[go: up one dir, main page]
More Web Proxy on the site http://driver.im/

US10092877B1 - Dust removal and desulfurization of FCC exhaust gas - Google Patents

Dust removal and desulfurization of FCC exhaust gas Download PDF

Info

Publication number
US10092877B1
US10092877B1 US15/618,975 US201715618975A US10092877B1 US 10092877 B1 US10092877 B1 US 10092877B1 US 201715618975 A US201715618975 A US 201715618975A US 10092877 B1 US10092877 B1 US 10092877B1
Authority
US
United States
Prior art keywords
flow
washing
vessel
liquid
ammonium sulfate
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Active
Application number
US15/618,975
Inventor
Jing Luo
Jun Zhang
Yongying LUO
Qiang Tan
Xiangjun Xu
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Jiangnan Environmental Protection Group Inc
Original Assignee
Jiangnan Environmental Protection Group Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Jiangnan Environmental Protection Group Inc filed Critical Jiangnan Environmental Protection Group Inc
Assigned to JIANGSU NEW CENTURY JIANGNAN ENVIRONMENTAL PROTECTION INC., LTD. reassignment JIANGSU NEW CENTURY JIANGNAN ENVIRONMENTAL PROTECTION INC., LTD. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: LUO, JING, LUO, Yongying, TAN, QIANG, XU, XIANGJUN, ZHANG, JUN
Assigned to JIANGNAN ENVIRONMENTAL PROTECTION GROUP INC. reassignment JIANGNAN ENVIRONMENTAL PROTECTION GROUP INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: JIANGSU NEW CENTURY JIANGNAN ENVIRONMENTAL PROTECTION INC., LTD.
Priority to US15/938,272 priority Critical patent/US10213739B2/en
Priority to PCT/CN2018/096796 priority patent/WO2018214990A1/en
Application granted granted Critical
Publication of US10092877B1 publication Critical patent/US10092877B1/en
Priority to US16/168,018 priority patent/US10343110B2/en
Priority to US16/429,418 priority patent/US10471383B2/en
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

Classifications

    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/46—Removing components of defined structure
    • B01D53/48—Sulfur compounds
    • B01D53/50—Sulfur oxides
    • B01D53/501—Sulfur oxides by treating the gases with a solution or a suspension of an alkali or earth-alkali or ammonium compound
    • B01D53/502—Sulfur oxides by treating the gases with a solution or a suspension of an alkali or earth-alkali or ammonium compound characterised by a specific solution or suspension
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D47/00—Separating dispersed particles from gases, air or vapours by liquid as separating agent
    • B01D47/06—Spray cleaning
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D47/00—Separating dispersed particles from gases, air or vapours by liquid as separating agent
    • B01D47/06—Spray cleaning
    • B01D47/063—Spray cleaning with two or more jets impinging against each other
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/343—Heat recovery
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/46—Removing components of defined structure
    • B01D53/48—Sulfur compounds
    • B01D53/50—Sulfur oxides
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/46—Removing components of defined structure
    • B01D53/48—Sulfur compounds
    • B01D53/50—Sulfur oxides
    • B01D53/501—Sulfur oxides by treating the gases with a solution or a suspension of an alkali or earth-alkali or ammonium compound
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/46—Removing components of defined structure
    • B01D53/54—Nitrogen compounds
    • B01D53/56—Nitrogen oxides
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/46—Removing components of defined structure
    • B01D53/60—Simultaneously removing sulfur oxides and nitrogen oxides
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/74—General processes for purification of waste gases; Apparatus or devices specially adapted therefor
    • B01D53/75—Multi-step processes
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/74—General processes for purification of waste gases; Apparatus or devices specially adapted therefor
    • B01D53/77—Liquid phase processes
    • B01D53/78—Liquid phase processes with gas-liquid contact
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/74—General processes for purification of waste gases; Apparatus or devices specially adapted therefor
    • B01D53/86—Catalytic processes
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/74—General processes for purification of waste gases; Apparatus or devices specially adapted therefor
    • B01D53/86—Catalytic processes
    • B01D53/8621—Removing nitrogen compounds
    • B01D53/8625—Nitrogen oxides
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/74—General processes for purification of waste gases; Apparatus or devices specially adapted therefor
    • B01D53/86—Catalytic processes
    • B01D53/8621—Removing nitrogen compounds
    • B01D53/8625—Nitrogen oxides
    • B01D53/8628—Processes characterised by a specific catalyst
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/74—General processes for purification of waste gases; Apparatus or devices specially adapted therefor
    • B01D53/86—Catalytic processes
    • B01D53/90—Injecting reactants
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/96—Regeneration, reactivation or recycling of reactants
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01C—AMMONIA; CYANOGEN; COMPOUNDS THEREOF
    • C01C1/00—Ammonia; Compounds thereof
    • C01C1/24—Sulfates of ammonium
    • C01C1/245—Preparation from compounds containing nitrogen and sulfur
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G11/00—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
    • C10G11/14—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts
    • C10G11/18—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised-bed" technique
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
    • F22B1/00—Methods of steam generation characterised by form of heating method
    • F22B1/02—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers
    • F22B1/18—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers the heat carrier being a hot gas, e.g. waste gas such as exhaust gas of internal-combustion engines
    • F22B1/1892—Systems therefor not provided for in F22B1/1807 - F22B1/1861
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
    • B01D2252/10—Inorganic absorbents
    • B01D2252/102—Ammonia
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/30—Sulfur compounds
    • B01D2257/302—Sulfur oxides
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/40—Nitrogen compounds
    • B01D2257/404—Nitrogen oxides other than dinitrogen oxide
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2258/00—Sources of waste gases
    • B01D2258/02—Other waste gases
    • B01D2258/0283—Flue gases
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/40—Characteristics of the process deviating from typical ways of processing
    • C10G2300/405—Limiting CO, NOx or SOx emissions
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P70/00—Climate change mitigation technologies in the production process for final industrial or consumer products
    • Y02P70/10—Greenhouse gas [GHG] capture, material saving, heat recovery or other energy efficient measures, e.g. motor control, characterised by manufacturing processes, e.g. for rolling metal or metal working

Definitions

  • the present invention relates to the field of environmental protection technologies, and in particular to a method and an apparatus for denitrification and desulfurization of and dust removal from a fluid catalytic cracking (hereinafter, “FCC”) tail gas by an ammonia-based process.
  • FCC fluid catalytic cracking
  • FCC tail gas is characterized by large fine particulate level (particulates with a size of 0-10 ⁇ m account for 50% or more) and high SO 2 concentration (300-4500 mg/m 3 ).
  • the dust level fluctuates greatly; particularly when the catalyst loss occurs in a regenerator during the regular “soot blowing” process and in an extreme state of a high-temperature operation, the dust level is increased dramatically.
  • the dust may also contain nickel, vanadium or other heavy metal elements, thus affecting the quality of by-products, and affecting the recycling of sulfur. All these factors have increased the difficulty in effective management of tail gas pollution occurring during catalyst regeneration of a catalytic cracking unit.
  • dust removal from and desulfurization of the FCC tail gas may rely on the use of wet washing technology; however, the investment, operation and maintenance costs are high, and the construction period of the system is long. Moreover, these technical methods also have the problems such as high consumption of lye, large volume of waste water and others.
  • the existing sodium process is a disposable process, in which the desulfurization and dust removal operations have no need to be separated; however, high salt waste water is required to be treated, secondary pollution may be caused, and a large amount of catalyst may enter the washing liquid under the operating condition of catalyst loss, which may increase the treatment load of the waste solid, and waste the catalyst, thus affecting the long-term stable operation of the system.
  • Chinese Patent Application No. CN 104941423A disclosed a system for denitrification and desulfurization of and dust removal from an FCC regenerative tail gas by an ammonia-based process on Sep. 30, 2015.
  • the application discloses introducing the high-temperature tail gas containing the catalyst dust produced during the catalyst regeneration of a catalytic cracking unit to a waste heat recovery boiler I, where the temperature of the tail gas is reduced to 280-430° C., and the heat of the tail gas is utilized by the waste heat recovery boiler I to produce steam for output; entering the tail gas at 280-430° C.
  • the application discloses integrated desulfurization and dust removal technology by an ammonia-based process.
  • the absorption liquid containing ammonium sulfate is difficult to separate from the dust because the particle size of the catalyst dust is small.
  • the system necessitates that the dust level in the tail gas at the inlet is 30-800 mg/Nm 3 .
  • the dust removal and the desulfurization are carried out at the same time, and there is mutual interference, thus affecting the long-term stable operation of the apparatus.
  • FIG. 1 is a schematic illustration of apparatus in accordance with the principles of the invention.
  • FIG. 2 is a schematic illustration of apparatus in accordance with the principles of the invention.
  • FIG. 1 In FIG. 1 :
  • Ammonia-Bearing Liquid means a liquid comprising at least one ammonia or amine based compound, including but not limited to ammonium salts, ammonium ions (NH4+), ammonium sulfate, ammonium sulfite, and any combination thereof.
  • the liquid may be water.
  • Ammonia recovery means that fraction or percentage of ammonia added to a gas cleaning process that is subsequently captured and extracted from the process.
  • Dust means a particulate material fine enough to waft along gaseous flows, when handled, processed, or contacted. It includes but is not limited to aerosols, including solid aerosol particles and liquid aerosol particles, soot, charcoal, non-combusted coal, fine minerals, sand, gravel, salts, and any combination thereof.
  • exhaust means a flow of gas exiting an industrial or chemical process. It includes but is not limited to flue gas, tail gas, exhaust gases from ovens, furnaces, boilers, and/or generators. It may comprise combustion products derived from the combustion of air and flammable material, residual material from chemical processes, which may include water, nitrogen, and pollutants, such as particulate matter, soot, carbon monoxide, nitrogen oxides, and sulfur oxides. The exhaust of one process may be a gaseous input to another process.
  • Oxidation Rate means the percentage, calculated by mol percent, of a given material that has been converted into an identified more-oxidized species of the material. For example, in a mixture containing ammonia bearing species and sulfur oxides, if X mol % of the mixture is ammonium sulfate, Y mol % is ammonium sulfite, and Z mol % is some other ammonia, sulfur, and/or oxygen containing species with an oxidation potential greater than ammonium sulfate, because ammonium sulfate is the identified most-oxidized species, the oxidation rate of the mixture would be X mol %.
  • Spray Coverage is a divergence of spray from a nozzle or an array of nozzles. The greater is the divergence, the greater is the spray coverage.
  • “Sulfur Oxides or SO x ” means a chemical species containing sulfur and oxygen. It includes compounds such as sulfur monoxide (SO), sulfur dioxide (SO 2 ), sulfur trioxide (SO 3 ), higher sulfur oxides (SO 3 and SO 4 and polymeric condensates of them), disulfur monoxide (S 2 O), disulfur dioxide (S 2 O 2 ), and lower sulfur oxides (S 7 O 2 , S 6 O 2 , and S n O x , where n and x are any possible stoichiometric numerical values).
  • NO x means a chemical species containing nitrogen and oxygen.
  • Apparatus and methods for using ammonia to treat fluid catalytic cracking tail-gas are provided.
  • the apparatus and methods may include an oxidation section, an absorption section and a fine particulate control section in the absorption tower.
  • Functions of the oxidation section, absorption section and fine particulate control section in the absorption tower may be similar to those described in Chinese Invention Patent Application Nos. CN103301705B, entitled “Apparatus and method for controlling fine particulates in tail gas for desulfurization”, and CN104524948B, entitled “Ultra-low discharge method for integrated ultrasonic desulfurization and dust removal,” which are hereby incorporated by reference herein in their entireties, filed by the present applicants.
  • the apparatus and methods may operate stably for a long period of time.
  • Ammonium sulfate by-product obtained from the apparatus and methods may have high quality, high desulfurization rate, high denitrification rate, and high dust removal rate.
  • Cleaned tail gas may meet the requirement as specified by GB31570-2015 “Emission standard of pollutants for petroleum refining industry”.
  • the apparatus and methods may include dedusting by washing.
  • the washing may include washing with a liquid.
  • the liquid may include water.
  • the apparatus and methods may include desulfurization by an ammonia-based process. Dedusting and desulfurization may be carried out in 2 separated towers. 80% or more dust may be removed in the dedusting tower. Dedusting in the dedusting tower may lead to high quality reclaimed ammonium sulfate product. Dedusting in the dedusting tower may lead to a desirable final dust emission index.
  • the absorption tower may be a tower that does not have a cooling and washing section. The cooling and washing section may be omitted because of heat removal prior to entry into the absorption tower.
  • the apparatus may include a flow-through heat-exchanger in thermal communication with a flow that includes the tail-gas.
  • the heat exchanger may include a liquid coolant that is materially isolated from the flow.
  • the apparatus may include, downstream, along the flow, from the heat-exchanger, a dust-removal vessel.
  • the dust removal vessel may include a washing-liquid spray layer that is configured to spray washing liquid against the flow to remove dust from the flow.
  • the apparatus may include, downstream from the dust-removal vessel, a sulfur-dioxide absorption vessel.
  • the sulfur-dioxide absorption vessel may support a liquid circuit.
  • the liquid circuit may be configured to provide an ammonia-bearing liquid to a sprayer that is directed against the flow.
  • the liquid circuit may be configured to recirculate the liquid, after passing through the sprayer, to the sprayer.
  • the sulfur dioxide absorption vessel may include a desulfurization tower.
  • the desulfurization tower may include a sulfur dioxide absorption section.
  • the desulfurization tower may include, downstream from the sulfur dioxide absorption section, a fine particulate removal section.
  • the fine particulate removal section may include a washing layer.
  • the washing layer may include first sprayers configured to spray recycled dilute ammonium sulfate solution against the flow.
  • the washing layer may include, downstream from the first sprayers, second sprayers configured to spray recycled dilute ammonium sulfate solution against the flow.
  • the fine particulate removal section may include, downstream from the washing layer, a first demister.
  • the fine particulate removal section may include, downstream from the first demister, a second demister.
  • a ratio of sprayed solution to flow gas in a region between the first sprayers and the second sprayers may be a ratio that is not less than 1.1 L/m 3 .
  • a spray coverage rate of the first sprayers may be a rate that is not less than 120%.
  • the spray coverage rate may be a rate that is not less than 300%.
  • the sulfur dioxide absorption tower may be a sulfur dioxide absorption tower that does not have a flow-cooling section.
  • the apparatus may include a denitrification system.
  • the denitrification system may be configured to remove nitrogen from the flow.
  • the denitrification system may be disposed upstream along the flow, from the heat exchanger.
  • the denitrification system may be disposed upstream along the flow from the vessel.
  • the denitrification system may be disposed downstream along the flow, from the heat exchanger.
  • the dust-removal vessel may be disposed downstream from the denitrification system.
  • the apparatus may include a waste-heat recovery system.
  • the waste-heat recovery system may be disposed downstream from the denitrification system.
  • the waste-heat recovery system may be configured to remove heat from the flow.
  • the waste-heat recovery system may include a liquid coolant.
  • the coolant may be materially isolated from the flow.
  • the denitrification system may include a selective catalytic reduction reactor.
  • the reactor may have an ammonia injection grid at an inlet for the flow.
  • the reactor may have a flow rectifier configured to rectify the flow.
  • the dust removal vessel may include, transverse to a direction of the flow, first sprayers in a first washing-liquid spray layer.
  • the dust removal vessel may include, transverse to a direction of the flow, below the first layer, second sprayers in a second washing-liquid spray layer.
  • the sprayers may be configured to direct washing-liquid against the flow.
  • the first washing-liquid spray layer may be configured to dispense washing-liquid such that between the first and second washing-liquid layers washing-liquid is sprayed at a rate of 1.1 L washing-liquid per m3 flow moving up the tower.
  • the first washing-liquid spray layer may be configured to provide a spray coverage rate that is not less than 120%.
  • the total spray coverage rate of washing-liquid spray layers in the dedusting tower may be a rate that is not less than 200%.
  • the dust removal vessel may include, transverse to the flow, a demister.
  • the demister may include a baffle-type demister.
  • the demister may include a roof-ridge type demister.
  • the demister may include a wire mesh type demister.
  • the apparatus may include an evaporator that is configured to dewater ammonium sulfate in a feed.
  • the feed may be a feed that is generated by the sulfur-absorption vessel.
  • the evaporator may produce from the ammonium sulfate a slurry.
  • the reclamation system may be configured to pass the slurry through a cyclone.
  • the reclamation system may be configured to pass the slurry through a centrifuge.
  • the reclamation system may be configured to pass the slurry through a dryer.
  • the reclamation system may be configured to pass the slurry to a packaging machine.
  • the reclamation system may be configured to pass the slurry through, in order, a cyclone, a centrifuge a dryer, and a packaging machine.
  • the methods may include recovering in an indirect-contact heat exchanger heat from a flow that includes the tail-gas so that the temperature of the flow is reduced to 250-350° C.
  • the methods may include after the recovering removing dust from the flow in a first vessel.
  • the methods may include after the removing dust removing sulfur dioxide from the flow in a second vessel.
  • the methods may include after the removing sulfur dioxide: a first washing the flow by spraying recycled dilute ammonium sulfate solution against the flow at a first location; again washing the flow by spraying recycled dilute ammonium sulfate solution against the flow at a second location downstream from the first location; a first demisting the flow at a third location downstream from the second location; and again demisting the flow at a fourth location downstream from the third location.
  • the first washing may provide a ratio of sprayed solution to flow gas in a region between the first and second location that is not less than 1.1 L/m 3 .
  • the first washing may produce a spray coverage rate not less than 120%.
  • the first washing may produce a spray coverage rate not less than 300%.
  • the removing dust may include removing no less than 80% of dust that enters the first vessel in the flow.
  • the methods may include treating the flow, in the second vessel, with ammonia to produce ammonium sulfate; and adding heat to the ammonium sulfate with an evaporator to thicken the ammonium sulfate.
  • the methods may include, at an inlet to the first vessel, receiving the flow when the flow has a temperature in the range 250-350° C.
  • the methods may include, at an inlet to the first vessel, receiving the flow when the flow has a temperature in the range 140 to 220° C.
  • the methods may include after the recovering heat, and before the removing dust, removing nitrogen oxides from the flow.
  • the removing sulfur dioxide may include treating the flow with ammonia, the method further comprising collecting ammonium sulfate that is produced by the treating.
  • the methods may include, after the removing nitrogen oxides, recovering other heat from the flow.
  • the other heat may be removed by a second-stage waste heat recovery system.
  • the methods may include, prior to the recovering heat, receiving the flow in a state in which the flow has a temperature in the range 580 to 950° C.
  • the methods may include, prior to the recovering heat, receiving the flow in a state in which the flow has a NO x concentration in the range 100 to 1200 mg/Nm 3 .
  • the methods may include, prior to the recovering heat, receiving the flow in a state in which the flow has an SO 2 concentration in the range 200 to 30,000 mg/Nm 3 .
  • the methods may include, prior to the recovering heat, receiving the flow in a state in which the flow has a dust level in the range 50 to 10,000 mg/Nm 3 .
  • the flow may have a dust level greater than 4,500 mg/Nm 3 .
  • the methods may include, prior to the recovering heat, receiving the flow in a state in which the flow has a temperature in the range 600 to 670° C.
  • the methods may include, prior to the recovering heat, receiving the flow in a state in which the flow has a NO x concentration in the range 250 to 800 mg/Nm 3 .
  • the methods may include, prior to the recovering heat, receiving the flow in a state in which the flow has an SO 2 concentration in the range 500 to 5,000 mg/Nm 3 .
  • the methods may include, prior to recovering heat, receiving the flow in a state in which the flow has a dust level in the range 100 to 300 mg/Nm 3 .
  • the methods may include, after the recovering other heat, and before removing dust: discharging the flow from a second-stage waste heat recovery system in a state in which the flow has a temperature in the range 140 to 220° C.; and producing from the other heat: low-pressure steam in the range 0.3 to 0.8 MPa from tail-gas heat; and preheated soft water.
  • the removing sulfur dioxide may include collecting a sulfur-dioxide-absorption reflux liquid at a bottom of the second vessel.
  • the removing sulfur dioxide may include feeding a first aliquot of the absorption liquid to an ammonium sulfate post-processing system.
  • the post-processing system may include an ammonium sulfate reclamation system.
  • the removing sulfur dioxide may include oxidizing a second aliquot of the absorption liquid using an oxygen-containing gas.
  • the removing sulfur dioxide may include adding to the second aliquot an ammonia-containing absorbent.
  • the removing sulfur dioxide may include delivering the second aliquot to sprayers in an absorption section of the absorption tower.
  • the oxygen-containing gas may include air.
  • the ammonia-containing absorbent may include aqueous ammonia.
  • the aqueous ammonia may be 10-25% ammonia by weight.
  • the ammonia-containing absorbent may include anhydrous ammonia.
  • the second aliquot may be in the range 75-98% by weight of the total absorption liquid delivered to the sprayers.
  • the methods may include:
  • the temperature of the FCC tail gas entering the first-stage waste heat recovery system may be in the range 580 to 950° C.
  • the NO x concentration may be in the range 100 to 1200 mg/Nm 3
  • the SO 2 concentration may be in the range 200 to 30000 mg/Nm 3
  • the total dust level may be in the range 50 to 10000 mg/Nm 3
  • the temperature of the FCC tail gas entering the first-stage waste heat recovery system may be in the range 600 to 670° C.
  • the NO x concentration may be in the range 250 to 800 mg/Nm 3
  • the SO 2 concentration may be in the range 500 to 5000 mg/Nm 3
  • the total dust level may be in the range 100 to 300 mg/Nm 3 .
  • the temperature of the FCC tail gas after being cooled in the second-stage waste heat recovery system in Step (2) may be in the range 140 to 220° C.
  • the FCC tail gas discharged after the treatment in the second-stage waste heat recovery system may be fed into the dust removal and desulfurization system.
  • the second-stage waste heat recovery system may cool the FCC tail gas in such a manner that a low-pressure steam of 0.3 to 0.8 MPa, preheated soft water, or both, are produced as by-products.
  • a bottom absorption liquid may be collected at the bottom of the absorption tower, a part of the bottom absorption liquid may be fed to the ammonium sulfate post-processing system.
  • a different part of the bottom absorption liquid may be oxidized with an oxygen-containing gas, replenished with an ammonia-containing absorbent, and then recycled to the absorption section of the absorption tower.
  • the oxygen-containing gas may be air; the ammonia-containing absorbent may be aqueous ammonia of 10-25% by weight and/or anhydrous ammonia.
  • the bottom absorption liquid recycled to the absorption section may account for 75-98% by weight of the total bottom absorption liquid.
  • the apparatus may include a first-stage waste heat recovery system, a denitrification system, a dust removal and desulfurization system, a tail gas exhaust system, and an ammonium sulfate post-processing system.
  • the denitrification system may have a feed port for a denitrification reducing agent provided thereon.
  • the dust removal and desulfurization system may include a dedusting tower and an absorption tower disposed separately. The top and the bottom of the absorption tower may be connected respectively to the tail gas exhaust system and the ammonium sulfate post-processing system.
  • the dedusting tower may be provided with two or more layers of washing liquid sprayers, and one or more layer of demisters disposed above the washing liquid sprayers in the dedusting tower.
  • the absorption tower may include, sequentially, from bottom to top, an oxidation section, an absorption section, and a fine particulate control section.
  • the absorption section may be provided with two or more layers of sprayers.
  • the fine particulate control section may be provided with one to four evenly spaced washing layers that spray dilute ammonium sulfate solution.
  • the first-stage waste heat recovery system, the denitrification system, the dedusting tower, and the absorption tower may be connected in sequence.
  • the apparatus may include or involve a second-stage waste heat recovery system, where the first-stage waste heat recovery system, the denitrification system, the second-stage waste heat recovery system, the dedusting tower, and the absorption tower may be connected in sequence.
  • the denitrification system may include a selective catalytic reduction (SCR) reactor.
  • a rectifier may be provided in an upper part of the SCR reactor, and an ammonia injection grid may be provided at an inlet for the FCC tail gas of the SCR reactor.
  • 2 to 5 or more layers of washing liquid sprayers may be provided in the dedusting tower, in which the liquid to gas ratio between each layer of the washing liquid sprayers is not less than 1.1 L/m 3 , the spray coverage rate is not less than 120%, and the total spray coverage rate of the dedusting tower is not less than 200%.
  • the dedusting tower may include 1 to 5 or more layers of demisters.
  • the demister of the dedusting tower may be one or more of a baffle demister, a roof type demister, and a wire mesh demister.
  • the bottom of the dedusting tower may be connected with a washing circulation pump, which may be connected to a filtering system.
  • the filtering system may be connected respectively to the top of the dedusting tower and the absorption tower.
  • An inlet for process water to the dedusting tower may be provided at an upper portion of the dedusting tower.
  • Fresh process water or evaporated condensed water may be added to the dedusting tower via the inlet for process water to the dedusting tower, and may enter a circulating washing liquid. A part of the circulating washing liquid may pass through the filtering system and may enter the absorption tower.
  • Absorption spray liquid may be collected in the oxidation section, and oxidized with air. Most of the slurry may be recycled and, a part of the slurry may enter the ammonium sulfate post-processing system, in which a product ammonium sulfate may be obtained.
  • the slurry for recycling and the slurry entering the ammonium sulfate post-processing system for evaporation and recrystallization may be drawn from different positions of the oxidation section.
  • the oxidation section may include 3 to 8 or more layers of gas-liquid dispersion enhancers.
  • the absorption tower may include 2 to 4 or more layers of sprayers in the absorption section, in which the liquid to gas ratio between each layer of the sprayers in the absorption section may be a ratio that is not less than 1.1 L/m 3 , the spray coverage rate may be a rate that is not less than 120%, and the total spray coverage rate of the absorption section may be a rate that is not less than 300%.
  • One or more layers of demisters may be provided above the sprayers in the absorption section.
  • the absorption section may include 1 to 5 or more layers of demisters.
  • the demister may include one or more of a baffle demister, a roof type demister, and a wire mesh demister.
  • the washing layer may be provided with two or more layers of sprayers in the washing layer. Two or more layers of demisters may be provided above the sprayers in the washing layer, in which the liquid to gas ratio between each layer of the sprayers in the washing layer may be a ratio that is not less than 1.1 L/m 3 , the spray coverage rate may be a rate that is not less than 120%, and the total spray coverage rate of the fine particulate control section may be a rate that is not less than 300%.
  • the washing layer may include 1 to 4 or more layers of sprayers.
  • the washing layer may include 1 to 5 or more layers of demisters.
  • the demister of the washing layer may include one or more of a baffle demister, a roof type demister, and a wire mesh demister.
  • the bottom of the absorption tower may be connected with one or more absorption circulation pumps.
  • the absorption section of the absorption tower may include an inlet for absorption spray liquid.
  • Two absorption circulation pumps may be present.
  • Several branches of conduit may run from one of the pumps respectively to the inlet for the absorption spray liquid and the ammonium sulfate post-processing system.
  • the other absorption circulation pump may be directly connected to the inlet for the absorption spray liquid.
  • An inlet for process water to the absorption tower may be provided at an upper portion of the absorption tower.
  • An inlet for an ammonia-containing absorbent and an inlet for air as oxidant may be provided at a lower portion of the absorption tower.
  • Fresh process water or evaporated condensed water may be added to the absorption tower via an inlet for process water to the absorption tower.
  • the FCC tail gas After sulfur dioxide is absorbed in the absorption section, the FCC tail gas enters the fine particulate control section, and may be cyclically or repeatedly washed with dilute ammonium sulfate solution to absorb fine particulates (including fine particulates in dust entrained in the FCC tail gas, escaped ammonia, and aerosol).
  • the size of the fine particulates may be ⁇ 1 ⁇ m.
  • the tail gas exhaust system is may be disposed lateral to or on the top of the desulfurization unit.
  • the tail gas exhaust system may include a tail gas exhaust chimney when disposed on the top of the desulfurization unit.
  • the ammonium sulfate post-processing system includes an evaporation and crystallization device, a cyclone, a centrifuge, a dryer, and a packaging machine connected in sequence, in which the evaporation and crystallization device is connected to the absorption tower.
  • a shell, internals, and pipes of the dedusting tower, the absorption tower, and the evaporation and crystallization device may include a corrosion resistant material.
  • the material may include one or more of a stainless-steel material of Grade 022Cr17Ni12Mo2, a dual-phase steel material of Grade 00Cr22Ni5Mo3N, a dual-phase steel material of Grade 00Cr25Ni6Mo2N, a titanium-based material, and Q235B steel lined with epoxy glass flakes.
  • An outlet of the first-stage waste heat recovery boiler may be connected to a gas inlet of the denitrification system.
  • An outlet of the denitrification system may be connected to the second-stage waste heat recovery system.
  • the methods may include:
  • the temperature of the FCC tail gas entering the first-stage waste heat recovery system may be in the range 580 to 950° C.
  • the NO x concentration may be in the range 100 to 1200 mg/Nm 3
  • the SO 2 concentration may be in the range 200 to 30000 mg/Nm 3
  • the total dust level may be in the range 50 to 10000 mg/Nm 3 .
  • the temperature of the FCC tail gas entering the first-stage waste heat recovery system may be in the range 600 to 670° C.
  • the NO x concentration may be in the range 250 to 800 mg/Nm 3
  • the SO 2 concentration may be in the range 500 to 5000 mg/Nm 3
  • the total dust level may be in the range 100 to 300 mg/Nm 3 .
  • the denitrification in Step (1) is may be performed using a selective catalytic reduction (SCR) process or a selective non-catalytic reduction (SNCR) process.
  • SCR selective catalytic reduction
  • SNCR selective non-catalytic reduction
  • the reducing agent used during denitrification may include ammonia, urea or both.
  • the temperature of the FCC tail gas after being further cooled in the second-stage waste heat recovery system in Step (1) may be in the range 140 to 220° C.
  • the second-stage waste heat recovery system may be employed for further cooling the FCC tail gas.
  • the second-stage waste heat recovery system may be omitted.
  • FCC tail gas discharged after the treatment in the second-stage waste heat recovery system may be fed into the dust removal and desulfurization system.
  • the FCC tail gas may be cooled by the second-stage waste heat recovery system in such a manner that a low-pressure steam of 0.3 to 0.8 MPa and a preheated soft water, or both, are produced as by-products.
  • a bottom absorption liquid may be collected at the bottom of the absorption tower, a part of which is fed to the ammonium sulfate post-processing system, and another part of which is oxidized with an oxygen-containing gas, replenished with an ammonia-containing absorbent, and then recycled to the absorption section of the absorption tower.
  • the oxygen-containing gas may include air.
  • the ammonia-containing absorbent may include aqueous ammonia of 10-25% by weight and/or liquid ammonia.
  • Bottom absorption liquid recycled to the absorption section may account for 75-98% by weight of the total bottom absorption liquid.
  • the NO x concentration may be ⁇ 100 mg/Nm 3
  • the SO 2 concentration may be ⁇ 50 mg/Nm 3
  • the total dust level may be ⁇ 20 mg/Nm 3
  • the dust removal efficiency may be an efficiency that is not less than 80%.
  • By-product ammonium sulfate obtained from the methods may meet the requirement as specified by GB535-1995.
  • the reagents and starting materials used in the apparatus and methods may be commercially available.
  • the Example is provided to illustrate the apparatus and methods.
  • the parameters required for ammonium sulfate of the first grade are: N content ⁇ 21%, water content ⁇ 0.3%, and free acid content ⁇ 0.05%.
  • An FCC tail gas 8 enters a denitrification and waste water recovery system 123 , for the purpose of denitrification under the action of ammonia 7 .
  • the FCC tail gas after denitrification enters a dedusting system 44 , and then enters a desulfurization system 45 for further desulfurization under the action of ammonia 7 .
  • the cleaned tail gas 10 after desulfurization is discharged via a tail gas processing system, and the remaining circulating liquid enters an ammonium sulfate post-processing system 6 , where ammonium sulfate 9 is obtained.
  • the specific process is as shown in FIG. 1 .
  • the Example relates to apparatus and methods for denitrification and desulfurization of and dust removal from an FCC tail gas by an ammonia-based process that has a processing capacity of 100,0000 tons/year.
  • the apparatus includes first-stage waste heat recovery system 1 , denitrification system 2 , second-stage waste heat recovery system 3 , dust removal and desulfurization system 4 , tail gas exhaust system 5 , and ammonium sulfate post-processing system 6 .
  • First-stage waste heat recovery system 1 has inlet 11 of the FCC tail gas provided thereon.
  • Denitrification system 2 is connected to the first-stage waste heat recovery system 1 , and has feed port 21 of a denitrification reducing agent thereon.
  • Second-stage waste heat recovery system 3 is connected to denitrification system 2 .
  • Dust removal and desulfurization system 4 includes a dedusting unit and a desulfurization unit disposed separately.
  • the dedusting unit is dedusting tower 41 connected to second-stage waste heat recovery system 3 ; and the desulfurization unit is an absorption tower 42 connected to the dedusting tower 41 and also to the tail gas exhaust system 5 and ammonium sulfate post-processing system 6 respectively.
  • Absorption tower 42 has an inlet 421 for an ammonia-containing absorbent and an inlet 422 for air as oxidant provided thereon, as shown in FIG. 2 .
  • the dedusting tower is includes 3 layers of washing liquid sprayer, where the liquid to gas ratio between each layer of the washing liquid sprayers is 1.5 L/m 3 , the spray coverage rate of each single layer is 140%, and the total spray coverage rate of the dedusting tower is not less than 400%.
  • the dedusting tower is provided with 2 layers of demisters in an upper part of the dedusting tower, which are baffle and roof type demisters.
  • the dust removal efficiency of the dedusting tower is not less than 80%.
  • the solid-containing washing liquid obtained in the dedusting tower is fed to a filtering system for solid removal, and the washing liquid removed of the solid is recycled for washing the FCC tail gas.
  • an oxidation tank is provided at the bottom of absorption tower 42 , and 3 layers of absorption liquid sprayers are provided in an absorption section above the inlet for the tail gas, where the liquid to gas ratio between each layer of the washing liquid sprayers is 1.25 L/m 3 , the spray coverage rate of each single layer is 130%, and the total spray coverage rate of the dedusting tower is 320%.
  • the absorption liquids of different oxidation rates are drawn from 2 different positions of the oxidation tank at the bottom of the absorption tower, one of which is recycled for absorption by an absorption circulation pump, and the other of which is fed to an evaporation and crystallization system.
  • a fine particulate control section is provided above the absorption section, and the fine particulate control section includes 2 layers of demisters provided above a sprayer layer in a washing layer, and the demisters in the washing layer are roof type and wire mesh demisters.
  • ammonium sulfate post-processing system 6 includes an evaporation and crystallization device 61 , a cyclone 62 , a centrifuge 63 , a dryer 64 , and a packaging machine 65 connected in sequence.
  • the shell, the internals, and the pipes of the dedusting tower, the absorption tower, and the evaporation and crystallization device are all made with a stainless-steel material of Grade 022Cr17Ni12Mo2.
  • the method of the Example includes:
  • the desulfurization efficiency in the Example is 98.9%, and the denitrification efficiency is 90%.
  • the denitrification efficiency is ⁇ 90%, the desulfurization efficiency is 98.9%, the NO x concentration in the cleaned tail gas is 35 mg/Nm 3 , the SO 2 concentration is 38 mg/Nm 3 , the dust level is 11.5 mg/Nm 3 , and the nitrogen content in the by-product ammonium sulfate is 21.06%. Normal performance can be achieved under the operating condition of catalyst loss.
  • CN104941423A is taken as a Comparative Example, in which the tail gas of 100,0000 tons/year produced during the catalyst regeneration of a catalytic cracking unit is treated, where the flow rate of the tail gas is 135000 Nm 3 /h, the temperature is 950° C., the moisture content is 12%, the nitrogen oxide concentration is 360 mg/Nm 3 , the sulfur dioxide concentration is 2300 mg/Nm 3 , the dust level is 150 mg/Nm 3 , and the desulphurizing agent is 99.6% liquid ammonia.
  • the denitrification efficiency is ⁇ 88.9%
  • the desulfurization efficiency is 98.5%
  • the NO x concentration in the cleaned tail gas is 38 mg/Nm 3
  • the SO 2 concentration is 32 mg/Nm 3
  • the dust level is lower than 15 mg/Nm 3
  • the nitrogen content in the by-product ammonium sulfate is 20.8%.

Landscapes

  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Environmental & Geological Engineering (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • General Chemical & Material Sciences (AREA)
  • Analytical Chemistry (AREA)
  • Health & Medical Sciences (AREA)
  • Biomedical Technology (AREA)
  • Organic Chemistry (AREA)
  • Sustainable Development (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Sustainable Energy (AREA)
  • Physics & Mathematics (AREA)
  • Thermal Sciences (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Inorganic Chemistry (AREA)
  • Treating Waste Gases (AREA)
  • Chimneys And Flues (AREA)

Abstract

Apparatus and methods for denitrification and desulfurization of and dust removal from an FCC tail gas by an ammonia-based process. The apparatus may include a first-stage waste heat recovery system, a denitrification system, a dust removal and desulfurization system, a tail gas exhaust system, and an ammonium sulfate post-processing system. The dust removal and desulfurization system may include a dedusting tower and an absorption tower disposed separately. The top and the bottom of the absorption tower may be connected respectively to the tail gas exhaust system and the ammonium sulfate post-processing system. The absorption tower may include sequentially, from bottom to top, an oxidation section, an absorption section, and a fine particulate control section. The methods may be implemented with the apparatus.

Description

This application claims priority under 35 U.S.C. § 119 of Chinese Patent Application No. 201710379458.6, filed on May 25, 2017, which is hereby incorporated in its entirety herein.
TECHNICAL FIELD
The present invention relates to the field of environmental protection technologies, and in particular to a method and an apparatus for denitrification and desulfurization of and dust removal from a fluid catalytic cracking (hereinafter, “FCC”) tail gas by an ammonia-based process.
BACKGROUND
SO2, NOx, and dust are main pollutants in the atmosphere and are a significant source of smog. With the increasing total industrial pollution load and the limited environmental receptivity, the emission standards need to be further improved, to reduce the concentration of emitted pollutants. FCC tail gas is characterized by large fine particulate level (particulates with a size of 0-10 μm account for 50% or more) and high SO2 concentration (300-4500 mg/m3). Moreover, the dust level fluctuates greatly; particularly when the catalyst loss occurs in a regenerator during the regular “soot blowing” process and in an extreme state of a high-temperature operation, the dust level is increased dramatically. In addition to silicon, aluminum and other metal elements, the dust may also contain nickel, vanadium or other heavy metal elements, thus affecting the quality of by-products, and affecting the recycling of sulfur. All these factors have increased the difficulty in effective management of tail gas pollution occurring during catalyst regeneration of a catalytic cracking unit.
At present, dust removal from and desulfurization of the FCC tail gas may rely on the use of wet washing technology; however, the investment, operation and maintenance costs are high, and the construction period of the system is long. Moreover, these technical methods also have the problems such as high consumption of lye, large volume of waste water and others. The existing sodium process is a disposable process, in which the desulfurization and dust removal operations have no need to be separated; however, high salt waste water is required to be treated, secondary pollution may be caused, and a large amount of catalyst may enter the washing liquid under the operating condition of catalyst loss, which may increase the treatment load of the waste solid, and waste the catalyst, thus affecting the long-term stable operation of the system.
Chinese Patent Application No. CN 104941423A disclosed a system for denitrification and desulfurization of and dust removal from an FCC regenerative tail gas by an ammonia-based process on Sep. 30, 2015. The application discloses introducing the high-temperature tail gas containing the catalyst dust produced during the catalyst regeneration of a catalytic cracking unit to a waste heat recovery boiler I, where the temperature of the tail gas is reduced to 280-430° C., and the heat of the tail gas is utilized by the waste heat recovery boiler I to produce steam for output; entering the tail gas at 280-430° C. into a denitrification system for denitrification; after adequate reaction on the surface of the denitrification catalyst in the denitrification reactor, entering the tail gas into a waste heat recovery boiler II via a tail gas vent; removing the sulfur dioxide and nitrogen oxide in the tail gas by reacting with ammonia, with ammonium sulfate being produced as a by-product, and removing the catalyst dust in the tail gas at the same time, to obtain a cleaned gas that is discharged up to standard.
The application discloses integrated desulfurization and dust removal technology by an ammonia-based process. During the long-term operation and practice, where the same absorption liquid is used for dust removal and desulfurization, the absorption liquid containing ammonium sulfate is difficult to separate from the dust because the particle size of the catalyst dust is small. The system necessitates that the dust level in the tail gas at the inlet is 30-800 mg/Nm3. The dust removal and the desulfurization are carried out at the same time, and there is mutual interference, thus affecting the long-term stable operation of the apparatus. Especially when the dust level in the tail gas at the inlet is as high as 5000 mg/Nm3, and the total amount exceeds 2 tons under an accident condition, ingredients entering the circulating absorption liquid will affect the absorption liquid, and the desulfurization and dust removal efficiencies, and the absorption liquid cannot be effectively separated from the dust, thus affecting the quality of the product ammonium sulfate.
It would therefore be desirable to provide improved apparatus and methods for recovery-type deep denitrification, desulfurization and dust removal to overcome shortcomings in the prior art.
BRIEF DESCRIPTION OF THE DRAWINGS
The objects and advantages of the invention will be apparent upon consideration of the following detailed description, taken in conjunction with the accompanying drawings, in which like reference characters refer to like parts throughout, and in which:
FIG. 1 is a schematic illustration of apparatus in accordance with the principles of the invention; and
FIG. 2 is a schematic illustration of apparatus in accordance with the principles of the invention.
 REFERENCE NUMERALS
In FIG. 1:
  • 6: ammonium sulfate post-processing system;
  • 7: ammonia;
  • 8: FCC tail gas;
  • 9: ammonium sulfate;
  • 10: cleaned tail gas;
  • 123: denitrification and waste heat recovery system;
  • 44: dedusting system;
  • 45: desulfurization system;
    In FIG. 2:
  • 1: first-stage waste heat recovery system;
  • 2: denitrification system;
  • 3: second-stage waste heat recovery system;
  • 4: dust removal and desulfurization system;
  • 5: tail gas exhaust system;
  • 6: ammonium sulfate post-processing system;
  • 11: inlet for FCC tail gas;
  • 21: feed port for denitrification reducing agent;
  • 41: dedusting tower;
  • 42: absorption tower;
  • 421: inlet for ammonia-containing absorbent;
  • 422: inlet for air as oxidant;
  • 61: evaporation and crystallization device;
  • 62: cyclone;
  • 63: centrifuge;
  • 64: dryer;
The drawings are exemplifications of the principles of the invention and are not intended to limit the invention to the particular embodiments illustrated.
DETAILED DESCRIPTION Definitions
“Ammonia-Bearing Liquid” means a liquid comprising at least one ammonia or amine based compound, including but not limited to ammonium salts, ammonium ions (NH4+), ammonium sulfate, ammonium sulfite, and any combination thereof. The liquid may be water.
“Ammonia recovery” means that fraction or percentage of ammonia added to a gas cleaning process that is subsequently captured and extracted from the process.
“Dust” means a particulate material fine enough to waft along gaseous flows, when handled, processed, or contacted. It includes but is not limited to aerosols, including solid aerosol particles and liquid aerosol particles, soot, charcoal, non-combusted coal, fine minerals, sand, gravel, salts, and any combination thereof.
“Exhaust” means a flow of gas exiting an industrial or chemical process. It includes but is not limited to flue gas, tail gas, exhaust gases from ovens, furnaces, boilers, and/or generators. It may comprise combustion products derived from the combustion of air and flammable material, residual material from chemical processes, which may include water, nitrogen, and pollutants, such as particulate matter, soot, carbon monoxide, nitrogen oxides, and sulfur oxides. The exhaust of one process may be a gaseous input to another process.
“Oxidation Rate” means the percentage, calculated by mol percent, of a given material that has been converted into an identified more-oxidized species of the material. For example, in a mixture containing ammonia bearing species and sulfur oxides, if X mol % of the mixture is ammonium sulfate, Y mol % is ammonium sulfite, and Z mol % is some other ammonia, sulfur, and/or oxygen containing species with an oxidation potential greater than ammonium sulfate, because ammonium sulfate is the identified most-oxidized species, the oxidation rate of the mixture would be X mol %.
“Spray Coverage” is a divergence of spray from a nozzle or an array of nozzles. The greater is the divergence, the greater is the spray coverage.
“Sulfur Oxides or SOx” means a chemical species containing sulfur and oxygen. It includes compounds such as sulfur monoxide (SO), sulfur dioxide (SO2), sulfur trioxide (SO3), higher sulfur oxides (SO3 and SO4 and polymeric condensates of them), disulfur monoxide (S2O), disulfur dioxide (S2O2), and lower sulfur oxides (S7O2, S6O2, and SnOx, where n and x are any possible stoichiometric numerical values).
“NOx” means a chemical species containing nitrogen and oxygen.
In the event that the above definitions or a description stated elsewhere in this application is inconsistent with a meaning (explicit or implicit) that is commonly used, set forth in a dictionary, or stated in a source incorporated by reference into this application, the application and the claim terms in particular are understood to be construed according to the definition or description in this application, and not according to the common definition, dictionary definition, or the definition that was incorporated by reference. In the event that a claim term can only be understood if it is construed by a dictionary, a definition set forth in the Kirk-Othmer Encyclopedia of Chemical Technology, 5th Edition, 2005, (John Wiley & Sons, Inc.) shall control, if provided therein.
Apparatus and methods for using ammonia to treat fluid catalytic cracking tail-gas are provided.
The apparatus and methods may include an oxidation section, an absorption section and a fine particulate control section in the absorption tower. Functions of the oxidation section, absorption section and fine particulate control section in the absorption tower may be similar to those described in Chinese Invention Patent Application Nos. CN103301705B, entitled “Apparatus and method for controlling fine particulates in tail gas for desulfurization”, and CN104524948B, entitled “Ultra-low discharge method for integrated ultrasonic desulfurization and dust removal,” which are hereby incorporated by reference herein in their entireties, filed by the present applicants.
The apparatus and methods may operate stably for a long period of time. Ammonium sulfate by-product obtained from the apparatus and methods may have high quality, high desulfurization rate, high denitrification rate, and high dust removal rate. Cleaned tail gas may meet the requirement as specified by GB31570-2015 “Emission standard of pollutants for petroleum refining industry”.
The apparatus and methods may include dedusting by washing. The washing may include washing with a liquid. The liquid may include water. The apparatus and methods may include desulfurization by an ammonia-based process. Dedusting and desulfurization may be carried out in 2 separated towers. 80% or more dust may be removed in the dedusting tower. Dedusting in the dedusting tower may lead to high quality reclaimed ammonium sulfate product. Dedusting in the dedusting tower may lead to a desirable final dust emission index. The absorption tower may be a tower that does not have a cooling and washing section. The cooling and washing section may be omitted because of heat removal prior to entry into the absorption tower.
The apparatus may include a flow-through heat-exchanger in thermal communication with a flow that includes the tail-gas. The heat exchanger may include a liquid coolant that is materially isolated from the flow. The apparatus may include, downstream, along the flow, from the heat-exchanger, a dust-removal vessel. The dust removal vessel may include a washing-liquid spray layer that is configured to spray washing liquid against the flow to remove dust from the flow. The apparatus may include, downstream from the dust-removal vessel, a sulfur-dioxide absorption vessel. The sulfur-dioxide absorption vessel may support a liquid circuit. The liquid circuit may be configured to provide an ammonia-bearing liquid to a sprayer that is directed against the flow. The liquid circuit may be configured to recirculate the liquid, after passing through the sprayer, to the sprayer.
The sulfur dioxide absorption vessel may include a desulfurization tower. The desulfurization tower may include a sulfur dioxide absorption section. The desulfurization tower may include, downstream from the sulfur dioxide absorption section, a fine particulate removal section.
The fine particulate removal section may include a washing layer. The washing layer may include first sprayers configured to spray recycled dilute ammonium sulfate solution against the flow. The washing layer may include, downstream from the first sprayers, second sprayers configured to spray recycled dilute ammonium sulfate solution against the flow.
The fine particulate removal section may include, downstream from the washing layer, a first demister. The fine particulate removal section may include, downstream from the first demister, a second demister.
In the washing layer, in operation, a ratio of sprayed solution to flow gas in a region between the first sprayers and the second sprayers may be a ratio that is not less than 1.1 L/m3.
In the washing layer, in operation, a spray coverage rate of the first sprayers may be a rate that is not less than 120%.
In the washing layer, in operation, the spray coverage rate may be a rate that is not less than 300%.
The sulfur dioxide absorption tower may be a sulfur dioxide absorption tower that does not have a flow-cooling section.
The apparatus may include a denitrification system. The denitrification system may be configured to remove nitrogen from the flow. The denitrification system may be disposed upstream along the flow, from the heat exchanger. The denitrification system may be disposed upstream along the flow from the vessel.
The denitrification system may be disposed downstream along the flow, from the heat exchanger.
The dust-removal vessel may be disposed downstream from the denitrification system.
The apparatus may include a waste-heat recovery system. The waste-heat recovery system may be disposed downstream from the denitrification system. The waste-heat recovery system may be configured to remove heat from the flow. The waste-heat recovery system may include a liquid coolant. The coolant may be materially isolated from the flow.
The denitrification system may include a selective catalytic reduction reactor. The reactor may have an ammonia injection grid at an inlet for the flow. The reactor may have a flow rectifier configured to rectify the flow.
The dust removal vessel may include, transverse to a direction of the flow, first sprayers in a first washing-liquid spray layer. The dust removal vessel may include, transverse to a direction of the flow, below the first layer, second sprayers in a second washing-liquid spray layer. The sprayers may be configured to direct washing-liquid against the flow.
The first washing-liquid spray layer may be configured to dispense washing-liquid such that between the first and second washing-liquid layers washing-liquid is sprayed at a rate of 1.1 L washing-liquid per m3 flow moving up the tower. The first washing-liquid spray layer may be configured to provide a spray coverage rate that is not less than 120%. The total spray coverage rate of washing-liquid spray layers in the dedusting tower may be a rate that is not less than 200%.
The dust removal vessel may include, transverse to the flow, a demister.
The demister may include a baffle-type demister.
The demister may include a roof-ridge type demister.
The demister may include a wire mesh type demister.
The apparatus may include an evaporator that is configured to dewater ammonium sulfate in a feed. The feed may be a feed that is generated by the sulfur-absorption vessel. The evaporator may produce from the ammonium sulfate a slurry.
The reclamation system may be configured to pass the slurry through a cyclone.
The reclamation system may be configured to pass the slurry through a centrifuge.
The reclamation system may be configured to pass the slurry through a dryer.
The reclamation system may be configured to pass the slurry to a packaging machine.
The reclamation system may be configured to pass the slurry through, in order, a cyclone, a centrifuge a dryer, and a packaging machine.
The methods may include recovering in an indirect-contact heat exchanger heat from a flow that includes the tail-gas so that the temperature of the flow is reduced to 250-350° C. The methods may include after the recovering removing dust from the flow in a first vessel. The methods may include after the removing dust removing sulfur dioxide from the flow in a second vessel.
The methods may include after the removing sulfur dioxide: a first washing the flow by spraying recycled dilute ammonium sulfate solution against the flow at a first location; again washing the flow by spraying recycled dilute ammonium sulfate solution against the flow at a second location downstream from the first location; a first demisting the flow at a third location downstream from the second location; and again demisting the flow at a fourth location downstream from the third location.
The first washing may provide a ratio of sprayed solution to flow gas in a region between the first and second location that is not less than 1.1 L/m3.
The first washing may produce a spray coverage rate not less than 120%.
The first washing may produce a spray coverage rate not less than 300%.
The removing dust may include removing no less than 80% of dust that enters the first vessel in the flow.
The methods may include treating the flow, in the second vessel, with ammonia to produce ammonium sulfate; and adding heat to the ammonium sulfate with an evaporator to thicken the ammonium sulfate.
The methods may include, at an inlet to the first vessel, receiving the flow when the flow has a temperature in the range 250-350° C.
The methods may include, at an inlet to the first vessel, receiving the flow when the flow has a temperature in the range 140 to 220° C.
The methods may include after the recovering heat, and before the removing dust, removing nitrogen oxides from the flow.
The removing sulfur dioxide may include treating the flow with ammonia, the method further comprising collecting ammonium sulfate that is produced by the treating.
The methods may include, after the removing nitrogen oxides, recovering other heat from the flow. The other heat may be removed by a second-stage waste heat recovery system.
The methods may include, prior to the recovering heat, receiving the flow in a state in which the flow has a temperature in the range 580 to 950° C.
The methods may include, prior to the recovering heat, receiving the flow in a state in which the flow has a NOx concentration in the range 100 to 1200 mg/Nm3.
The methods may include, prior to the recovering heat, receiving the flow in a state in which the flow has an SO2 concentration in the range 200 to 30,000 mg/Nm3.
The methods may include, prior to the recovering heat, receiving the flow in a state in which the flow has a dust level in the range 50 to 10,000 mg/Nm3. The flow may have a dust level greater than 4,500 mg/Nm3.
The methods may include, prior to the recovering heat, receiving the flow in a state in which the flow has a temperature in the range 600 to 670° C.
The methods may include, prior to the recovering heat, receiving the flow in a state in which the flow has a NOx concentration in the range 250 to 800 mg/Nm3.
The methods may include, prior to the recovering heat, receiving the flow in a state in which the flow has an SO2 concentration in the range 500 to 5,000 mg/Nm3.
The methods may include, prior to recovering heat, receiving the flow in a state in which the flow has a dust level in the range 100 to 300 mg/Nm3.
The methods may include, after the recovering other heat, and before removing dust: discharging the flow from a second-stage waste heat recovery system in a state in which the flow has a temperature in the range 140 to 220° C.; and producing from the other heat: low-pressure steam in the range 0.3 to 0.8 MPa from tail-gas heat; and preheated soft water.
The removing sulfur dioxide may include collecting a sulfur-dioxide-absorption reflux liquid at a bottom of the second vessel. The removing sulfur dioxide may include feeding a first aliquot of the absorption liquid to an ammonium sulfate post-processing system. The post-processing system may include an ammonium sulfate reclamation system. The removing sulfur dioxide may include oxidizing a second aliquot of the absorption liquid using an oxygen-containing gas. The removing sulfur dioxide may include adding to the second aliquot an ammonia-containing absorbent. The removing sulfur dioxide may include delivering the second aliquot to sprayers in an absorption section of the absorption tower.
The oxygen-containing gas may include air.
The ammonia-containing absorbent may include aqueous ammonia. The aqueous ammonia may be 10-25% ammonia by weight.
The ammonia-containing absorbent may include anhydrous ammonia.
In the delivering, the second aliquot may be in the range 75-98% by weight of the total absorption liquid delivered to the sprayers.
The methods may include:
(1) entering the FCC tail gas sequentially into the first-stage waste heat recovery system and the denitrification system for cooling and denitrification respectively, in which the temperature of the tail gas is reduced to 250-350° C.;
(2) after treatment in the denitrification system, entering the discharged FCC tail gas into the dust removal and desulfurization system, for dust removal in the dedusting tower and desulfurization in the absorption tower respectively; and, after treatment in the denitrification system, further recovering heat from the discharged FCC tail gas in the second-stage waste heat recovery system, and then entering the discharged FCC tail gas into the dust removal and desulfurization system; and
(3) discharging the cleaned tail gas after desulfurization via the tail gas exhaust system, and collecting the by-product ammonium sulfate in the ammonium sulfate post-processing system.
The temperature of the FCC tail gas entering the first-stage waste heat recovery system may be in the range 580 to 950° C., the NOx concentration may be in the range 100 to 1200 mg/Nm3, the SO2 concentration may be in the range 200 to 30000 mg/Nm3, and the total dust level may be in the range 50 to 10000 mg/Nm3; and the temperature of the FCC tail gas entering the first-stage waste heat recovery system may be in the range 600 to 670° C., the NOx concentration may be in the range 250 to 800 mg/Nm3, the SO2 concentration may be in the range 500 to 5000 mg/Nm3, and the total dust level may be in the range 100 to 300 mg/Nm3.
The temperature of the FCC tail gas after being cooled in the second-stage waste heat recovery system in Step (2) may be in the range 140 to 220° C. The FCC tail gas discharged after the treatment in the second-stage waste heat recovery system may be fed into the dust removal and desulfurization system. The second-stage waste heat recovery system may cool the FCC tail gas in such a manner that a low-pressure steam of 0.3 to 0.8 MPa, preheated soft water, or both, are produced as by-products.
During the desulfurization process, a bottom absorption liquid may be collected at the bottom of the absorption tower, a part of the bottom absorption liquid may be fed to the ammonium sulfate post-processing system. A different part of the bottom absorption liquid may be oxidized with an oxygen-containing gas, replenished with an ammonia-containing absorbent, and then recycled to the absorption section of the absorption tower. The oxygen-containing gas may be air; the ammonia-containing absorbent may be aqueous ammonia of 10-25% by weight and/or anhydrous ammonia. The bottom absorption liquid recycled to the absorption section may account for 75-98% by weight of the total bottom absorption liquid.
The apparatus may include a first-stage waste heat recovery system, a denitrification system, a dust removal and desulfurization system, a tail gas exhaust system, and an ammonium sulfate post-processing system. The denitrification system may have a feed port for a denitrification reducing agent provided thereon. The dust removal and desulfurization system may include a dedusting tower and an absorption tower disposed separately. The top and the bottom of the absorption tower may be connected respectively to the tail gas exhaust system and the ammonium sulfate post-processing system. The dedusting tower may be provided with two or more layers of washing liquid sprayers, and one or more layer of demisters disposed above the washing liquid sprayers in the dedusting tower. The absorption tower may include, sequentially, from bottom to top, an oxidation section, an absorption section, and a fine particulate control section. The absorption section may be provided with two or more layers of sprayers. The fine particulate control section may be provided with one to four evenly spaced washing layers that spray dilute ammonium sulfate solution.
The first-stage waste heat recovery system, the denitrification system, the dedusting tower, and the absorption tower may be connected in sequence.
The apparatus may include or involve a second-stage waste heat recovery system, where the first-stage waste heat recovery system, the denitrification system, the second-stage waste heat recovery system, the dedusting tower, and the absorption tower may be connected in sequence.
The denitrification system may include a selective catalytic reduction (SCR) reactor. A rectifier may be provided in an upper part of the SCR reactor, and an ammonia injection grid may be provided at an inlet for the FCC tail gas of the SCR reactor.
In some embodiments, 2 to 5 or more layers of washing liquid sprayers may be provided in the dedusting tower, in which the liquid to gas ratio between each layer of the washing liquid sprayers is not less than 1.1 L/m3, the spray coverage rate is not less than 120%, and the total spray coverage rate of the dedusting tower is not less than 200%. The dedusting tower may include 1 to 5 or more layers of demisters.
The demister of the dedusting tower may be one or more of a baffle demister, a roof type demister, and a wire mesh demister.
The bottom of the dedusting tower may be connected with a washing circulation pump, which may be connected to a filtering system. The filtering system may be connected respectively to the top of the dedusting tower and the absorption tower. An inlet for process water to the dedusting tower may be provided at an upper portion of the dedusting tower.
Fresh process water or evaporated condensed water may be added to the dedusting tower via the inlet for process water to the dedusting tower, and may enter a circulating washing liquid. A part of the circulating washing liquid may pass through the filtering system and may enter the absorption tower.
Absorption spray liquid may be collected in the oxidation section, and oxidized with air. Most of the slurry may be recycled and, a part of the slurry may enter the ammonium sulfate post-processing system, in which a product ammonium sulfate may be obtained. The slurry for recycling and the slurry entering the ammonium sulfate post-processing system for evaporation and recrystallization may be drawn from different positions of the oxidation section. The oxidation section may include 3 to 8 or more layers of gas-liquid dispersion enhancers.
The absorption tower may include 2 to 4 or more layers of sprayers in the absorption section, in which the liquid to gas ratio between each layer of the sprayers in the absorption section may be a ratio that is not less than 1.1 L/m3, the spray coverage rate may be a rate that is not less than 120%, and the total spray coverage rate of the absorption section may be a rate that is not less than 300%.
One or more layers of demisters may be provided above the sprayers in the absorption section. The absorption section may include 1 to 5 or more layers of demisters.
The demister may include one or more of a baffle demister, a roof type demister, and a wire mesh demister.
The washing layer may be provided with two or more layers of sprayers in the washing layer. Two or more layers of demisters may be provided above the sprayers in the washing layer, in which the liquid to gas ratio between each layer of the sprayers in the washing layer may be a ratio that is not less than 1.1 L/m3, the spray coverage rate may be a rate that is not less than 120%, and the total spray coverage rate of the fine particulate control section may be a rate that is not less than 300%. The washing layer may include 1 to 4 or more layers of sprayers. The washing layer may include 1 to 5 or more layers of demisters.
The demister of the washing layer may include one or more of a baffle demister, a roof type demister, and a wire mesh demister.
The bottom of the absorption tower may be connected with one or more absorption circulation pumps. The absorption section of the absorption tower may include an inlet for absorption spray liquid. Two absorption circulation pumps may be present. Several branches of conduit may run from one of the pumps respectively to the inlet for the absorption spray liquid and the ammonium sulfate post-processing system. The other absorption circulation pump may be directly connected to the inlet for the absorption spray liquid. An inlet for process water to the absorption tower may be provided at an upper portion of the absorption tower. An inlet for an ammonia-containing absorbent and an inlet for air as oxidant may be provided at a lower portion of the absorption tower.
Fresh process water or evaporated condensed water may be added to the absorption tower via an inlet for process water to the absorption tower.
After sulfur dioxide is absorbed in the absorption section, the FCC tail gas enters the fine particulate control section, and may be cyclically or repeatedly washed with dilute ammonium sulfate solution to absorb fine particulates (including fine particulates in dust entrained in the FCC tail gas, escaped ammonia, and aerosol). The size of the fine particulates may be ≤1 μm.
The tail gas exhaust system is may be disposed lateral to or on the top of the desulfurization unit. The tail gas exhaust system may include a tail gas exhaust chimney when disposed on the top of the desulfurization unit.
The ammonium sulfate post-processing system includes an evaporation and crystallization device, a cyclone, a centrifuge, a dryer, and a packaging machine connected in sequence, in which the evaporation and crystallization device is connected to the absorption tower.
A shell, internals, and pipes of the dedusting tower, the absorption tower, and the evaporation and crystallization device may include a corrosion resistant material. The material may include one or more of a stainless-steel material of Grade 022Cr17Ni12Mo2, a dual-phase steel material of Grade 00Cr22Ni5Mo3N, a dual-phase steel material of Grade 00Cr25Ni6Mo2N, a titanium-based material, and Q235B steel lined with epoxy glass flakes.
An outlet of the first-stage waste heat recovery boiler may be connected to a gas inlet of the denitrification system. An outlet of the denitrification system may be connected to the second-stage waste heat recovery system.
The methods may include:
(1) entering the FCC tail gas sequentially into the first-stage waste heat recovery system and the denitrification system for cooling and denitrification respectively, in which the temperature of the tail gas is reduced to 250-350° C.;
(2) after treatment in the denitrification system, entering the discharged FCC tail gas into the dust removal and desulfurization system after passing through the second-stage waste heat recovery system, for dust removal in the dedusting tower and desulfurization in the absorption tower respectively; and
(3) discharging the cleaned tail gas after desulfurization via the tail gas exhaust system, and collecting the by-product ammonium sulfate in the ammonium sulfate post-processing system.
The temperature of the FCC tail gas entering the first-stage waste heat recovery system may be in the range 580 to 950° C., the NOx concentration may be in the range 100 to 1200 mg/Nm3, the SO2 concentration may be in the range 200 to 30000 mg/Nm3, and the total dust level may be in the range 50 to 10000 mg/Nm3. The temperature of the FCC tail gas entering the first-stage waste heat recovery system may be in the range 600 to 670° C., the NOx concentration may be in the range 250 to 800 mg/Nm3, the SO2 concentration may be in the range 500 to 5000 mg/Nm3, and the total dust level may be in the range 100 to 300 mg/Nm3.
The denitrification in Step (1) is may be performed using a selective catalytic reduction (SCR) process or a selective non-catalytic reduction (SNCR) process. The reducing agent used during denitrification may include ammonia, urea or both.
The temperature of the FCC tail gas after being further cooled in the second-stage waste heat recovery system in Step (1) may be in the range 140 to 220° C.
The second-stage waste heat recovery system may be employed for further cooling the FCC tail gas. In some embodiments, the second-stage waste heat recovery system may be omitted. When the second-stage waste heat recovery system is present, FCC tail gas discharged after the treatment in the second-stage waste heat recovery system may be fed into the dust removal and desulfurization system. The FCC tail gas may be cooled by the second-stage waste heat recovery system in such a manner that a low-pressure steam of 0.3 to 0.8 MPa and a preheated soft water, or both, are produced as by-products.
During the desulfurization process in Step (2), a bottom absorption liquid may be collected at the bottom of the absorption tower, a part of which is fed to the ammonium sulfate post-processing system, and another part of which is oxidized with an oxygen-containing gas, replenished with an ammonia-containing absorbent, and then recycled to the absorption section of the absorption tower.
The oxygen-containing gas may include air.
The ammonia-containing absorbent may include aqueous ammonia of 10-25% by weight and/or liquid ammonia.
Bottom absorption liquid recycled to the absorption section may account for 75-98% by weight of the total bottom absorption liquid.
In the cleaned tail gas obtained by the methods, the NOx concentration may be ≤100 mg/Nm3, the SO2 concentration may be ≤50 mg/Nm3, the total dust level may be ≤20 mg/Nm3, and the dust removal efficiency may be an efficiency that is not less than 80%.
By-product ammonium sulfate obtained from the methods may meet the requirement as specified by GB535-1995.
The reagents and starting materials used in the apparatus and methods may be commercially available.
EXAMPLE
The Example is provided to illustrate the apparatus and methods.
In GB535-1995, the parameters required for ammonium sulfate of the first grade are: N content ≥21%, water content ≤0.3%, and free acid content ≤0.05%.
In the Example below, the process flow is as follows. An FCC tail gas 8 enters a denitrification and waste water recovery system 123, for the purpose of denitrification under the action of ammonia 7. The FCC tail gas after denitrification enters a dedusting system 44, and then enters a desulfurization system 45 for further desulfurization under the action of ammonia 7. The cleaned tail gas 10 after desulfurization is discharged via a tail gas processing system, and the remaining circulating liquid enters an ammonium sulfate post-processing system 6, where ammonium sulfate 9 is obtained. The specific process is as shown in FIG. 1.
The Example relates to apparatus and methods for denitrification and desulfurization of and dust removal from an FCC tail gas by an ammonia-based process that has a processing capacity of 100,0000 tons/year. The apparatus includes first-stage waste heat recovery system 1, denitrification system 2, second-stage waste heat recovery system 3, dust removal and desulfurization system 4, tail gas exhaust system 5, and ammonium sulfate post-processing system 6. First-stage waste heat recovery system 1 has inlet 11 of the FCC tail gas provided thereon. Denitrification system 2 is connected to the first-stage waste heat recovery system 1, and has feed port 21 of a denitrification reducing agent thereon. Second-stage waste heat recovery system 3 is connected to denitrification system 2. Dust removal and desulfurization system 4 includes a dedusting unit and a desulfurization unit disposed separately. In the Example, the dedusting unit is dedusting tower 41 connected to second-stage waste heat recovery system 3; and the desulfurization unit is an absorption tower 42 connected to the dedusting tower 41 and also to the tail gas exhaust system 5 and ammonium sulfate post-processing system 6 respectively. Absorption tower 42 has an inlet 421 for an ammonia-containing absorbent and an inlet 422 for air as oxidant provided thereon, as shown in FIG. 2.
In the Example, the dedusting tower is includes 3 layers of washing liquid sprayer, where the liquid to gas ratio between each layer of the washing liquid sprayers is 1.5 L/m3, the spray coverage rate of each single layer is 140%, and the total spray coverage rate of the dedusting tower is not less than 400%. The dedusting tower is provided with 2 layers of demisters in an upper part of the dedusting tower, which are baffle and roof type demisters. The dust removal efficiency of the dedusting tower is not less than 80%. The solid-containing washing liquid obtained in the dedusting tower is fed to a filtering system for solid removal, and the washing liquid removed of the solid is recycled for washing the FCC tail gas.
In the Example, an oxidation tank is provided at the bottom of absorption tower 42, and 3 layers of absorption liquid sprayers are provided in an absorption section above the inlet for the tail gas, where the liquid to gas ratio between each layer of the washing liquid sprayers is 1.25 L/m3, the spray coverage rate of each single layer is 130%, and the total spray coverage rate of the dedusting tower is 320%. The absorption liquids of different oxidation rates are drawn from 2 different positions of the oxidation tank at the bottom of the absorption tower, one of which is recycled for absorption by an absorption circulation pump, and the other of which is fed to an evaporation and crystallization system. A fine particulate control section is provided above the absorption section, and the fine particulate control section includes 2 layers of demisters provided above a sprayer layer in a washing layer, and the demisters in the washing layer are roof type and wire mesh demisters.
In the Example, ammonium sulfate post-processing system 6 includes an evaporation and crystallization device 61, a cyclone 62, a centrifuge 63, a dryer 64, and a packaging machine 65 connected in sequence.
In the Example, the shell, the internals, and the pipes of the dedusting tower, the absorption tower, and the evaporation and crystallization device are all made with a stainless-steel material of Grade 022Cr17Ni12Mo2.
The method of the Example includes:
(1) entering the FCC tail gas, where the flow rate is 262000 Nm3/h, the temperature of the FCC tail gas is 600-650° C., the dust level in the tail gas is 200 mg/Nm3 in a normal case, the SO2 concentration is 3550 mg/Nm3, the NOx concentration is 350 mg/Nm3, the dust level is 7500 mg/Nm3 under the operating condition of catalyst loss, the duration of catalyst loss is 2.5 h, and the catalyst lost is 4.91 t, into the first-stage waste heat recovery system where the temperature of the FCC tail gas is reduced to 335° C., and the heat of the tail gas is utilized by the first-stage waste heat recovery system to produce steam of 4 MPa at a rate of 11.6 t/h for output;
(2) entering the tail gas at 335° C. into the denitrification system and denitrifying with 5-15% aqueous ammonia, where after adequate reaction on the surface of the denitrification catalyst in the denitrification reactor, the nitrogen oxide content is decreased to 35 mg/Nm3, and the denitrification rate is 90%.
(3) after the treatment in the denitrification system, entering the tail gas into the second-stage waste heat recovery system via a tail gas vent, where steam of 0.6 MPa is produced at 3.3 t/h as a by-product, and the temperature of the tail gas is reduced to 166° C. in the second-stage waste heat recovery system;
(4) after the treatment in the second-stage waste heat recovery system, entering the discharged FCC tail gas into the dedusting tower for dust removal and into the absorption tower for desulfurization, where the solid-containing washing liquid obtained in the dedusting tower is fed to a filtering system for solid removal, and the washing liquid removed of the solid is recycled for washing the FCC tail gas; and the FCC tail gas entering the absorption tower is desulfurized with 5-15% aqueous ammonia; and
(5) after the desulfurization, discharging the cleaned tail gas via the tail gas exhaust system, where the NOx content is 35 mg/Nm3, the SO2 content is 38 mg/Nm3, the dust level is 11.5 mg/Nm3 in a normal case and is 21 mg/Nm3 under the operating condition of catalyst loss; the 40% ammonium sulfate solution produced as a by-product at about 4.7 t/h is evaporated and recrystallized, vortexed, separated by centrifugation, dried, and packaged, to obtain a finished product ammonium sulfate at 1.89 t/h, the quality of which (nitrogen content: 21.05%, water content: 0.2%, and free acid content: 0.03%) meets the requirements for ammonium sulfate of the first grade as specified by GB535-1995.
Illustrative analytical methods and instruments for detecting various indices in the Example is shown in Table 1. The parameters of main raw materials and the product are shown in Table 2.
TABLE 1
List of the methods and main instruments for detecting various indices
Item Standard analytical Instrument Instru-
No. monitored method and code and model ment #
1 Flue dust Determination of Laoying 8042448,
particulates and 3012H 08244496
sampling methods of model 18360886,
gaseous pollutants flue dust 1119051201
emitted from exhaust sampling
gas of stationary source instrument
GB/T16157-1996 Electronic
balance
B52245,
AB204-S
2 SO2 Determination of Testo 350 10#, 1#
sulphur dioxide from flue gas
exhausted gas of analytical
stationary source: fixed- instrument
potential electrolysis
HJ/T 57-2000
3 NOx Determination of Testo 350 10#, 1#
nitrogen dioxide from flue gas
exhausted gas of analytical
stationary source: fixed- instrument
potential electrolysis
HJ/T 693-2014
4 Ammonia Ambient air and exhaust Laoying 02085809,
gas-Determination of 3072H 2c5BP363
ammonia-Nessler's model 722
reagent spectro-
spectrophotometry photometer
HJ 533-2009
5 Oxygen Electrochemical method - Testo 350 10#, 1#
content Specifications and test flue gas
in the flue procedures for analytical
gas continuous emission instrument
monitoring systems of
flue gas emitted from
stationary sources
(Appendix B) (HJ/T 76-
2007)
6 Temper- Platinum resistor method TES-1310 /
ature of Determination of
the flue particulates and
gas sampling methods of
gaseous pollutants
emitted from exhaust gas
of stationary source
(GB/T 16157-1996)
7 Humidity Specifications and test Laoying 8042448,
of the flue procedures for 3012H 08244496
gas continuous emission model
monitoring systems of flue dust
flue gas emitted from sampling
stationary sources instrument
(Appendix B)
(HJ/T 76-2007)
8 Ammo- Ammonium sulfate (GB Analytical
nium 535-1995) balance,
sulfate PH meter
and other
known
laboratory
instruments
TABLE 2
Parameters of main raw materials and the product
No. Technic index Unit Value
 1 Flow rate of FCC tail gas Nm3/h 262000
 2 Temperature of the flue ° C. 600-650
gas at the inlet
 3 NOx concentration in the mg/Nm3 350
flue gas
 4 SO2 concentration in the mg/Nm3 3550
flue gas
 5 Dust level in the flue gas mg/Nm3 200
 6 NOx concentration in the mg/Nm3 35
flue gas at the outlet
 7 SO2 concentration in the mg/Nm3 38
flue gas at the outlet
 8 Dust level in the flue gas mg/Nm3 Normal case:
at the outlet 11.5;
Operating
condition of
catalyst loss: 21
 9 Absorption temperature ° C. 52-54
10 Ammonia recovery rate % 98.9
11 Quality of the product GB535: first
ammonium sulfate grade
The desulfurization efficiency in the Example is 98.9%, and the denitrification efficiency is 90%. The denitrification efficiency is ≥90%, the desulfurization efficiency is 98.9%, the NOx concentration in the cleaned tail gas is 35 mg/Nm3, the SO2 concentration is 38 mg/Nm3, the dust level is 11.5 mg/Nm3, and the nitrogen content in the by-product ammonium sulfate is 21.06%. Normal performance can be achieved under the operating condition of catalyst loss.
Comparative Example
CN104941423A is taken as a Comparative Example, in which the tail gas of 100,0000 tons/year produced during the catalyst regeneration of a catalytic cracking unit is treated, where the flow rate of the tail gas is 135000 Nm3/h, the temperature is 950° C., the moisture content is 12%, the nitrogen oxide concentration is 360 mg/Nm3, the sulfur dioxide concentration is 2300 mg/Nm3, the dust level is 150 mg/Nm3, and the desulphurizing agent is 99.6% liquid ammonia. In a normal case, the denitrification efficiency is ≥88.9%, the desulfurization efficiency is 98.5%, the NOx concentration in the cleaned tail gas is 38 mg/Nm3, the SO2 concentration is 32 mg/Nm3, the dust level is lower than 15 mg/Nm3, and the nitrogen content in the by-product ammonium sulfate is 20.8%.
However, the operating condition of catalyst loss is not taken into consideration and the following effects are obtained.
A large amount of dust enters the absorption liquid, such that the content of insoluble solid in the absorption liquid rises to 3% or higher. This causes the product ammonium sulfate to fail to be recrystallized and discharged. Even if the product ammonium sulfate could be discharged, the N content in the product would be decreased to 18% or below, and thus the product cannot be marketed. Moreover, the absorption circulation pump is clogged and worn, and the apparatus needs to be shut down to clean up the accumulated solids in the absorption tower. Dust level in the exhaust is 21 mg/Nm3.
The present disclosure illustrates principles of the invention and is not intended to limit the invention to the particular embodiments illustrated. All patents, patent applications, scientific papers, and any other referenced materials mentioned herein are incorporated by reference in their entirety. The principles of the invention encompass any possible combination of some or all of the various embodiments mentioned herein, described herein and/or incorporated herein. The principles of the invention encompass any possible combination that also specifically excludes any one or some of the various embodiments mentioned herein, described herein and/or incorporated herein.
All ranges and parameters disclosed herein are understood to encompass any and all subranges subsumed therein, and every number between the endpoints. For example, a stated range of “1 to 10” should be considered to include any and all subranges between (and inclusive of) the minimum value of 1 and the maximum value of 10; that is, all subranges beginning with a minimum value of 1 or more (e.g. 1 to 6.1), and ending with a maximum value of 10 or less (e.g. 2.3 to 9.4, 3 to 8, 4 to 7), and to each number 1, 2, 3, 4, 5, 6, 7, 8, 9, and 10 contained within the range. All percentages, ratios and proportions herein are by weight unless otherwise specified.
Thus, apparatus and methods for for using ammonia to treat fluid catalytic cracking tail-gas have been provided. Persons skilled in the art will appreciate that the present invention can be practiced by other than the described embodiments, which are presented for purposes of illustration rather than of limitation. The present invention is limited only by the claims that follow.

Claims (29)

What is claimed is:
1. An apparatus for using ammonia to treat fluid catalytic cracking tail-gas, the apparatus comprising:
a flow-through heat-exchanger in thermal communication with a flow that includes the tail-gas, the heat exchanger including a liquid coolant that is materially isolated from the flow;
downstream, along the flow, from the heat-exchanger, a dust-removal vessel that includes a washing-liquid spray layer configured to spray washing liquid against the flow to remove dust from the flow; and,
downstream from the dust-removal vessel, a sulfur dioxide absorption vessel that supports a liquid circuit configured to:
provide an ammonia-bearing liquid to a sprayer that is directed against the flow;
recirculate the liquid, after passing through the sprayer, to the sprayer; and
a denitrification system configured to remove nitrogen oxides from the flow, the denitrification system disposed downstream along the flow, from the heat exchanger, and upstream from the dust-removal vessel;
the dust-removal vessel further comprising, transverse to the flow:
a demister,
first savers in a first washing-liquid spray layer; and,
below the first layer, second sprayers in a second washing-liquid spray layer;
wherein the sprayers are configured to direct washing-liquid against the flow.
2. The apparatus of claim 1 wherein the sulfur dioxide absorption vessel includes a desulfurization tower that includes:
a sulfur dioxide absorption section; and,
downstream from the sulfur dioxide absorption section, a fine particulate removal section.
3. The apparatus of claim 2 wherein the fine particulate removal section includes:
a washing layer including:
first sprayers configured to spray recycled dilute ammonium sulfate solution against the flow;
downstream from the first sprayers, second sprayers configured to spray recycled dilute ammonium sulfate solution against the flow; and
downstream from the washing layer:
a first demister; and
downstream from the first demister, a second demister.
4. The apparatus of claim 3 wherein, in operation, a ratio of sprayed solution to flow gas in a region between the first sprayers and the second sprayers is not less than 1.1 L/m3.
5. The apparatus of claim 4 wherein, in operation, a spray coverage rate of the first sprayers is not less than 120%.
6. The apparatus of claim 5 wherein the spray coverage rate is not less than 300%.
7. The apparatus of claim 1 wherein the sulfur dioxide absorption vessel does not have a flow-cooling section.
8. The apparatus of claim 1, further comprising a waste-heat recovery system that is:
disposed downstream from the denitrification system and upstream from the dust-removal vessel; and
configured to remove heat from the flow; and
includes a liquid coolant that is materially isolated from the flow.
9. The apparatus claim 1 wherein the denitrification system includes a selective catalytic reduction reactor that has:
an ammonia injection grid at an inlet for the flow; and
a flow rectifier configured to rectify the flow.
10. The apparatus of claim 1 wherein:
the first washing-liquid spray layer is configured to dispense washing-liquid such that between the first and second washing-liquid layers washing-liquid is sprayed at a rate of 1.1 L washing-liquid per m3 flow moving up the dust-removal vessel;
the first washing-liquid spray layer is configured to provide a spray coverage rate that is not less than 120%; and
the total spray coverage rate of washing-liquid spray layers in the dust-removal vessel is not less than 200%.
11. The apparatus of claim 1 wherein:
the absorption vessel includes 2 to 4 layers of sprayers;
a liquid to gas ratio between each layer of the layers is a ratio that is not less than 1.1 L/m3;
a spray coverage rate is not less than 120%; and
a total spray coverage rate of the absorption vessel is not less than 300%.
12. A method of using ammonia to treat fluid catalytic cracking tail-gas, the method comprising:
recovering in an indirect-contact heat exchanger heat from a flow that includes the tail-gas so that the temperature of the flow is reduced to 250-350° C.;
then removing dust from the flow in a first vessel;
then removing sulfur dioxide from the flow in a second vessel; and
after the removing sulfur dioxide:
first washing the flow by spraying recycled dilute ammonium sulfate solution against the flow at a first location;
again washing the flow by spraying recycled dilute ammonium sulfate solution against the flow at a second location downstream from the first location;
first demisting the flow at a third location downstream from the second location; and
again demisting the flow at a fourth location downstream from the third location.
13. The method of claim 12 wherein the first washing provides a ratio of sprayed solution to flow gas in a region between the first and second location that is not less than 1.1 L/m3.
14. The method of claim 13 wherein the first washing produces a spray coverage rate not less than 120%.
15. The method of claim 14 wherein the first washing produces a spray coverage rate not less than 300%.
16. The method of claim 12 further including, prior to recovering heat, receiving the flow in a state in which the flow has a NOx concentration in the range 100 to 1200 mg/Nm3.
17. The method of claim 12 further including, prior to recovering heat, receiving the flow in a state in which the flow has an SO2 concentration in the range 200 to 30,000 mg/Nm3.
18. A method of using ammonia to treat fluid catalytic cracking tail-gas, the method comprising:
recovering in an indirect-contact heat exchanger heat from a flow that includes the tail-gas so that the temperature of the flow is reduced to 250-350° C.;
then removing dust from the flow in a first vessel; and
then removing sulfur dioxide from the flow in a second vessel;
wherein the removing dust comprises removing no less than 80% of dust that enters the first vessel in the flow.
19. The method of claim 18 further comprising:
treating the flow, in the second vessel, with ammonia to produce ammonium sulfate; and
adding heat to the ammonium sulfate with an evaporator to thicken the ammonium sulfate.
20. The method of claim 19 further comprising, at an inlet to the first vessel, receiving the flow when the flow has a temperature in the range 250-350° C.
21. The method of claim 19 further comprising, at an inlet to the first vessel, receiving the flow when the flow has a temperature in the range 140 to 220° C.
22. The method of claim 19 further comprising, after the recovering heat and before the removing dust, removing nitrogen oxides from the flow.
23. The method of claim 22 wherein the removing sulfur dioxide comprises treating the flow with ammonia, the method further comprising collecting ammonium sulfate that is produced by the treating.
24. The method of claim 22 further comprising, after the removing nitrogen oxides, recovering other heat from the flow.
25. A method of using ammonia to treat fluid catalytic cracking tail-gas, the method comprising:
recovering in an indirect-contact heat exchanger heat from a flow that includes the tail-gas so that the temperature of the flow is reduced to 250-350° C.;
then removing dust from the flow in a first vessel;
then removing sulfur dioxide from the flow in a second vessel; and
prior to the recovering heat, receiving the flow in a state in which the flow has a temperature in the range 580 to 950° C.
26. The method of claim 25 wherein the removing sulfur dioxide comprises treating the flow with ammonia, the method further comprising collecting ammonium sulfate that is produced by the treating.
27. The method of claim 25 further comprising removing nitrogen oxides from the flow.
28. The method of claim 25 further comprising:
treating the flow, in the second vessel, with ammonia to produce ammonium sulfate; and
adding heat to the ammonium sulfate with an evaporator to thicken the ammonium sulfate.
29. The method of claim 25 further including, prior to the recovering heat, receiving the flow in a state in which the flow has an SO2 concentration in the range 200 to 30,000 mg/Nm3.
US15/618,975 2017-05-25 2017-06-09 Dust removal and desulfurization of FCC exhaust gas Active US10092877B1 (en)

Priority Applications (4)

Application Number Priority Date Filing Date Title
US15/938,272 US10213739B2 (en) 2017-05-25 2018-03-28 Dust removal and desulfurization of FCC exhaust gas
PCT/CN2018/096796 WO2018214990A1 (en) 2017-05-25 2018-07-24 Dust removal and desulfurization of fcc exhaust gas
US16/168,018 US10343110B2 (en) 2017-05-25 2018-10-23 Dust removal and desulfurization of FCC exhaust gas
US16/429,418 US10471383B2 (en) 2017-05-25 2019-06-03 Dust removal and desulfurization of FCC exhaust gas

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
CN201710379458.6A CN107213785B (en) 2017-05-25 2017-05-25 Method and device for denitration, desulfurization and dust removal of FCC (fluid catalytic cracking) tail gas by ammonia process
CN201710379458 2017-05-25

Related Child Applications (1)

Application Number Title Priority Date Filing Date
US15/938,272 Continuation US10213739B2 (en) 2017-05-25 2018-03-28 Dust removal and desulfurization of FCC exhaust gas

Publications (1)

Publication Number Publication Date
US10092877B1 true US10092877B1 (en) 2018-10-09

Family

ID=59227497

Family Applications (4)

Application Number Title Priority Date Filing Date
US15/618,975 Active US10092877B1 (en) 2017-05-25 2017-06-09 Dust removal and desulfurization of FCC exhaust gas
US15/938,272 Active US10213739B2 (en) 2017-05-25 2018-03-28 Dust removal and desulfurization of FCC exhaust gas
US16/168,018 Active US10343110B2 (en) 2017-05-25 2018-10-23 Dust removal and desulfurization of FCC exhaust gas
US16/429,418 Active US10471383B2 (en) 2017-05-25 2019-06-03 Dust removal and desulfurization of FCC exhaust gas

Family Applications After (3)

Application Number Title Priority Date Filing Date
US15/938,272 Active US10213739B2 (en) 2017-05-25 2018-03-28 Dust removal and desulfurization of FCC exhaust gas
US16/168,018 Active US10343110B2 (en) 2017-05-25 2018-10-23 Dust removal and desulfurization of FCC exhaust gas
US16/429,418 Active US10471383B2 (en) 2017-05-25 2019-06-03 Dust removal and desulfurization of FCC exhaust gas

Country Status (10)

Country Link
US (4) US10092877B1 (en)
EP (1) EP3406320B1 (en)
JP (1) JP6397967B2 (en)
KR (1) KR102022305B1 (en)
CN (1) CN107213785B (en)
BR (1) BR102017013544B1 (en)
CA (1) CA2971738C (en)
CL (1) CL2017001698A1 (en)
MX (1) MX2017008446A (en)
WO (1) WO2018214990A1 (en)

Cited By (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10343110B2 (en) * 2017-05-25 2019-07-09 Jiangnan Environmental Protection Group Inc. Dust removal and desulfurization of FCC exhaust gas
CN111579437A (en) * 2020-05-27 2020-08-25 丹晟实业（上海）有限公司 Extraction testing arrangement of sulphur and nitrogen element content in haydite
CN111821856A (en) * 2020-07-29 2020-10-27 湖南萃智环保科技有限公司 Industrial flue gas denitration method
CN113384988A (en) * 2021-07-07 2021-09-14 西安鼎华联创工程技术有限公司 Ultra-clean dust removal system and dust removal method for dust removal and white removal of steel converter
US11224838B2 (en) 2019-12-26 2022-01-18 Jiangnan Environmental Protection Group Inc. Controlling aerosol production during absorption in ammonia-based desulfurization
CN114307492A (en) * 2021-12-29 2022-04-12 山东赛马力发电设备有限公司 Generating set exhaust treatment system
CN114353061A (en) * 2021-12-31 2022-04-15 北京博奇电力科技有限公司 Sintering flue gas ultralow emission system and method based on circulating fluidized bed desulfurization
CN114367164A (en) * 2021-12-23 2022-04-19 江苏徐海环境监测有限公司 Low-concentration large-flow high-efficiency waste gas treatment complete device
CN118543241A (en) * 2024-07-24 2024-08-27 北京中科润宇环保科技股份有限公司 Purification method and device for tail gas produced by denitration catalyst

Families Citing this family (21)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
MX2017008528A (en) 2017-06-14 2019-02-08 Jiangnan Environmental Prot Group Inc Automatic ammonia-adding system and method for ammonia-based desulfurization device.
CN108380023A (en) * 2018-03-12 2018-08-10 中国科学院过程工程研究所 A kind of flue gas desulfurization denitration dust-removing system and method
CN110732227B (en) * 2018-07-20 2023-02-21 江南环保集团股份有限公司 Method and device for treating acid gas
EP3597286A1 (en) * 2018-07-20 2020-01-22 Jiangnan Environmental Protection Group Inc. Acid gas treatment
US10669908B1 (en) 2018-12-03 2020-06-02 Wellhead Power Solutions, Llc Power generating systems and methods for reducing startup NOx emissions in fossile fueled power generation system
CN109772166B (en) * 2019-01-15 2021-12-24 华电电力科学研究院有限公司 Fuel gas distributed energy denitration system device and operation method
CN109908730A (en) * 2019-03-22 2019-06-21 刘振 A kind of glass reinforced plastic desulfurization tower to be removed the gred using waste heat power
CN110314505B (en) * 2019-07-17 2024-03-19 实联化工(江苏)有限公司 Device and method for treating ammonia-containing tail gas in ammonium drying section in alkali industry
CN110292859A (en) * 2019-07-23 2019-10-01 湖北陆盛环保工程有限公司 A kind of room temperature liquid phase catalytic reduction denitrification apparatus
CN110314519A (en) * 2019-07-31 2019-10-11 沛县祥龙矿山机械配件有限公司 A kind of desulfuration absorbing tower oxidation wind conveying device for thermal power plant
CN111036072A (en) * 2019-12-13 2020-04-21 西安润川环保科技有限公司 Flue gas treatment system
CN111068481A (en) * 2020-02-15 2020-04-28 丁昌林 Denitration and desulfurization device for industrial boiler
CN111068479A (en) * 2020-03-01 2020-04-28 河北唐银钢铁有限公司 Gas boiler HSNCR denitration spray gun
CN112295340B (en) * 2020-03-14 2022-12-30 太原四联环能科技有限公司 High-efficient recycle system of boiler waste heat
CN111561793B (en) * 2020-05-28 2024-02-06 中国石油化工股份有限公司 FCC catalyst spray drying tail gas heat recovery system and method thereof
CN111871075B (en) * 2020-07-17 2021-09-14 江苏乾宏能源科技有限公司 Be used for tar processing waste gas SOx/NOx control integration equipment
CN111992009B (en) * 2020-08-26 2022-05-17 安徽华创环保设备科技有限公司 Tail gas purification early warning system based on regeneration metal smelting
CN112717596A (en) * 2020-12-02 2021-04-30 安徽物迅科技有限公司 Building spraying dust removal system
CN112755755B (en) * 2021-01-13 2022-10-21 中国石油天然气集团有限公司 Device for realizing desulfurization and denitration under all working conditions
CN113082959B (en) * 2021-04-02 2023-07-18 江苏新世纪江南环保股份有限公司 Flue gas pretreatment method and device for ammonia desulfurization
CN113483343B (en) * 2021-05-31 2024-03-22 成都思达能环保设备有限公司 Dangerous waste flue gas treatment method and dangerous waste flue gas treatment system

Citations (197)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2810627A (en) 1953-02-26 1957-10-22 Texas Gulf Sulphur Co Recovery of sulfur dioxide from gases and production of ammonium sulphate
US3752877A (en) 1969-08-27 1973-08-14 Parsons Co Ralph M Recovery of sulfur compounds from tail gases
US3970740A (en) * 1973-06-13 1976-07-20 Exxon Research And Engineering Company Wet gas scrubbing process
US3983217A (en) 1973-09-26 1976-09-28 Kurashiki Boseki Kabushiki Kaisha Method for removing sulfur dioxide from waste gases
US4238317A (en) * 1979-08-20 1980-12-09 Standard Oil Company (Indiana) Catalytic cracking with reduced emission of noxious gases
US4294590A (en) 1978-11-09 1981-10-13 Linde Aktiengesellschaft Removal of undesired gaseous components from hot waste gases
US4324776A (en) 1980-12-08 1982-04-13 General Electric Company Mid-temperature H2 S removal process
US4378977A (en) 1978-11-09 1983-04-05 Linde Aktiengesellschaft Removal of undesired gaseous components from hot waste gases
US4552747A (en) 1984-06-20 1985-11-12 Gaa Engineered Systems, Inc. Temperature moderation of an oxygen enriched Claus sulfur plant
EP0212523A2 (en) 1985-08-15 1987-03-04 General Electric Company Process for the simultaneous absorption of sulfur oxides and production of ammonium sulfate
DE3733319A1 (en) 1987-10-02 1989-04-13 Krupp Koppers Gmbh Process for removing sulphur dioxide from flue gases
US5019361A (en) 1988-11-09 1991-05-28 Union Carbide Canada Limited Removal and recovery of sulphur dioxide from gas streams
US5106607A (en) 1987-12-23 1992-04-21 Rhone-Poulenc Chimie Multilobar catalysts for the conversion of sulfur containing gaseous effluents
US5632967A (en) 1995-09-19 1997-05-27 Goar, Allison & Associates, Inc. Process for the high pressure degassing of hydrogen sulfide from liquid sulfur
US6063352A (en) 1997-07-19 2000-05-16 Lurgi Lentjes Bischoff Gmbh Method of removing sulfur dioxide from flue gases, especially power plant flue gases and flue gases from garbage incinerator plants
US6066304A (en) * 1998-08-06 2000-05-23 Delores Pircon Process for removing sulfur dioxide out of a gas
US6203598B1 (en) * 1998-02-23 2001-03-20 Mitsubishi Heavy Industries, Ltd. Flue gas treating process and system
US6444185B1 (en) 1995-11-03 2002-09-03 Elf Exploration Production Process for recovering as sulfur the compounds H2S, SO2, COS and/or CS2 in a tail gas from a sulfur plant
US6508998B1 (en) 1996-10-28 2003-01-21 Gaa Engineered Systems, Inc. Temperature moderation of an oxygen enriched claus sulfur plant using an ejector
US6569398B2 (en) 2001-04-30 2003-05-27 Gaa Engineered Systems, Inc. Method for treating hydrogen sulfide-containing waste gases
US6616908B2 (en) 2000-08-31 2003-09-09 The Boc Group Plc Treatment of a gas stream containing hydrogen sulphide
US6752975B2 (en) * 2000-07-31 2004-06-22 Showa Denko K.K. Combustion exhaust gas treatment process and treatment apparatus
US6776974B1 (en) 1999-10-22 2004-08-17 Monsanto Enviro-Chem Systems, Inc. Process for the production of sulfur
CN1164480C (en) 2001-09-26 2004-09-01 南化集团研究院 Combined production of high concentration sulphuric acid by using acid gas containing hydrogen sulfide and sulphur
CN2640585Y (en) 2003-09-19 2004-09-15 镇江市江南环保设备研究所 Reinforced desulfurizing tower for smoke
CN2640584Y (en) 2003-09-17 2004-09-15 镇江市江南环保设备研究所 Integrated equipment for desulfurizing and discharging smoke
CN2668235Y (en) 2003-09-19 2005-01-05 镇江市江南环保设备研究所 High-speed smoke gas desulfurizing tower
WO2005007505A1 (en) 2003-07-22 2005-01-27 Knutsen Oas Shipping As Method and device for protecting a vessel’s loading space from excess pressure
WO2005113429A1 (en) 2004-04-22 2005-12-01 Fluor Technologies Corporation Configurations and methods for effluent gas treatment
CN2746972Y (en) 2004-12-07 2005-12-21 镇江市江南环保设备研究所 Multi-functional and combination type desulfurization tower
CN2746973Y (en) 2004-12-07 2005-12-21 镇江市江南环保设备研究所 Demister of nitrogen method desulfurization tower
CN2746971Y (en) 2004-12-07 2005-12-21 镇江市江南环保设备研究所 Desulfurization and denitration integrated flue-gas purification tower
CN2754711Y (en) 2004-12-07 2006-02-01 镇江市江南环保设备研究所 Smoke desulfurized filling tower from ammonia method
CN1251965C (en) 2002-06-25 2006-04-19 南化集团研究院 Preparation of high-concntration surlfuric acid using hydrogen sulfide contained acidic gas
CN2772609Y (en) 2004-12-07 2006-04-19 镇江市江南环保设备研究所 Oxidizing tower of smoke ammonia devulcanizer
CN2799060Y (en) 2005-06-28 2006-07-26 镇江市江南环保设备研究所 Empty tower type ammonia processed desulfurization tower
CN2799059Y (en) 2005-06-28 2006-07-26 镇江市江南环保设备研究所 Inside-crystallizing ammonia-processed desulfurization tower
WO2006113935A2 (en) 2005-04-20 2006-10-26 Fluor Technologies Corporation Configurations and methods for claus plant operation with variable sulfur content
CN1283346C (en) 2003-09-17 2006-11-08 镇江市江南环保设备研究所 Fuel coal smoke low oxidation rate desulfur method
CN1321723C (en) 2003-09-17 2007-06-20 镇江市江南环保设备研究所 Method of separating and recovering sulfur dioxide in smoke using ammonia method
US20070248518A1 (en) 2004-06-08 2007-10-25 Kirea Institute Of Science And Technology Desulfurizartion for Simultaneous Removal of Hydrogen Sulfide and Sulfur Dioxide
CN101085410A (en) 2007-07-16 2007-12-12 娄爱娟 Method and device for reclaiming sulfur dioxide from countercurrent flue gas
CN101108301A (en) 2006-07-21 2008-01-23 中国石油化工股份有限公司 Flue gas desulfurizing method and apparatus
US20080050299A1 (en) * 2006-08-25 2008-02-28 Bedell Michael W Wet gas scrubbing process
CN201030298Y (en) 2007-05-21 2008-03-05 江苏晟宜环保科技有限公司 One-segment type low-sulfur oxidizing catalyst reactor
US7351392B2 (en) 2004-03-03 2008-04-01 Shell Oil Company Process for the high recovery efficiency of sulfur from an acid gas stream
CN201052456Y (en) 2007-07-02 2008-04-30 江苏晟宜环保科技有限公司 Wrapped-tube catalytic oxidation reactor
CN100395006C (en) 2005-06-28 2008-06-18 江苏世纪江南环保有限公司 Void tower type ammonia desulfurizing process and apparatus
CN201109711Y (en) 2007-10-31 2008-09-03 镇海石化工程有限责任公司 Pool for storing underground liquid sulphur
CN201129965Y (en) 2007-11-20 2008-10-08 镇海石化工程有限责任公司 Sulfur condenser for sulfur recovery
CN201132102Y (en) 2007-12-11 2008-10-15 镇海石化工程有限责任公司 Ammine-burning device for recovering sulfur
CN100428979C (en) 2005-06-28 2008-10-29 江苏世纪江南环保有限公司 Ammonia desulfurizing process and apparatus with crystallization inside tower
CN201179415Y (en) 2008-02-14 2009-01-14 娄爱娟 Flue gas desulfurization purification column
CN100460045C (en) 2006-05-31 2009-02-11 中国石油化工股份有限公司 Process for disposing SOx in discharge gas
CN100475313C (en) 2007-02-13 2009-04-08 西安中宇软件科技有限责任公司 Device for the recovery and diffluence of sulfur dioxide and the system and method thereof
CN201231130Y (en) 2008-07-29 2009-05-06 中冶集团北京冶金设备研究设计总院 Flue gas desulfurization device for producing ammonia sulfate fertilizer
CN101422693A (en) 2008-11-24 2009-05-06 贵州开磷（集团）有限责任公司 Sulphuric acid tail-gas deep desulfurization method
CN101524620A (en) 2009-04-13 2009-09-09 山西晋丰环保工程设计有限公司 Segment-based ammonia flue gas desulfurization process and device thereof
CN201320447Y (en) 2008-10-27 2009-10-07 江苏新世纪江南环保有限公司 Integrated smoke purification device for desulphurization and denitration
CN201333376Y (en) 2008-11-14 2009-10-28 江苏新世纪江南环保有限公司 Flue gas desulfurization and denitration purifying device
CN101575103A (en) 2008-05-07 2009-11-11 北京丰汉工程咨询有限公司 Method for processing ammonium sulfate in acid gas desulfurization process
CN101585511A (en) 2009-06-25 2009-11-25 中国石油化工集团公司 Sulfur recycling technique
US7635408B2 (en) 2004-01-20 2009-12-22 Fluor Technologies Corporation Methods and configurations for acid gas enrichment
CN201380037Y (en) 2009-01-23 2010-01-13 江苏新世纪江南环保有限公司 Flue-gas cleaner with functions of desulphurization, denitration, concentration and crystal
CN201380040Y (en) 2009-01-23 2010-01-13 江苏新世纪江南环保有限公司 Combined device for purifying coal-fired flue gas
CN201380038Y (en) 2009-01-23 2010-01-13 江苏新世纪江南环保有限公司 Grid-type wet desulphurization device
CN201380039Y (en) 2009-01-23 2010-01-13 江苏新世纪江南环保有限公司 Double-tower flue gas desulphurization device
US7648692B2 (en) 2004-04-22 2010-01-19 Fluor Technologies Corporation COS-Claus configurations and methods
CN101642629A (en) 2008-08-08 2010-02-10 山东三维石化工程股份有限公司 Method for controlling amine solvent regeneration system
CN100588608C (en) 2007-04-30 2010-02-10 中国石油集团工程设计有限责任公司 The improvement low-temperature Claus sulfur recovery method
CN201423237Y (en) 2009-01-23 2010-03-17 江苏新世纪江南环保有限公司 Ammonia bubble crystallized flue gas desulfurizing device
CN201492952U (en) 2009-08-12 2010-06-02 江苏新世纪江南环保有限公司 Flue gas heat source heat pipe-type evaporation device of byproduct in ammonia process of flue gas desulfurization
CN101274750B (en) 2007-12-29 2010-06-30 江苏晟宜环保科技有限公司 Tail gas-recycled sulfur recovery method
US7754471B2 (en) 2004-03-03 2010-07-13 Shell Oil Company Process for the high recovery efficiency of sulfur from an acid gas stream
CN201529487U (en) 2009-10-30 2010-07-21 江苏新世纪江南环保有限公司 Gas cleaning device for liquid phase catalysis de-nitration
CN201529488U (en) 2009-10-30 2010-07-21 江苏新世纪江南环保有限公司 Gas ammonia washing combined sintering smoke desulphurization device
CN201537456U (en) 2009-08-12 2010-08-04 江苏新世纪江南环保有限公司 Flue gas heat exchange type evaporator of flue gas desulfurization side product by ammonia method
CN101274196B (en) 2007-12-11 2010-12-08 镇海石化工程有限责任公司 Desulphurization method of amine liquid with high removal rate of hydrogen sulfide
CN101182926B (en) 2007-12-14 2011-01-26 镇海石化工程有限责任公司 Stove-fuel flow online control device and method thereof
CN101519192B (en) 2009-03-27 2011-02-09 成都赛普瑞兴科技有限公司 Low temperature Claus sulfur recovery process and device therefor
US7910077B2 (en) 2004-11-09 2011-03-22 Fluor Technologies Corporation Configurations and methods for SOx removal in oxygen-containing gases
CN102012034A (en) 2010-12-06 2011-04-13 山东三维石化工程股份有限公司 Multifunctional exhaust incinerator for sulfur recovery facility
CN101579600B (en) 2009-05-04 2011-04-20 何金整 Ammonia desulfurization technology and device utilizing high potential energy
CN101579602B (en) 2009-06-12 2011-05-04 山西晋丰环保工程设计有限公司 Energy-saving and high-quality ammonia desulphurization process for ammonia sulfate recovery
CN101576261B (en) 2008-05-07 2011-05-11 北京丰汉工程咨询有限公司 Combustion and catalytic reduction method for acid gas
CN102061206A (en) 2010-12-02 2011-05-18 山东三维石化工程股份有限公司 Pressure reduction gas desulfurization method
CN101456541B (en) 2008-12-16 2011-05-25 山东三维石化工程股份有限公司 Selecting and packing method of catalyst for sulphur preparation
CN101274204B (en) 2007-03-28 2011-06-22 成都华西化工研究所 Absorbing agent for removing and recovering sulfur dioxide from gaseous mixture
CN201912884U (en) 2011-01-06 2011-08-03 江苏新世纪江南环保有限公司 Ammonia desulfurizer with two-level gas distributors
CN201912885U (en) 2011-01-06 2011-08-03 江苏新世纪江南环保有限公司 Desulfurizing and impurity removing integrated purifying device for sintering flue gas
US20110195008A1 (en) 2008-10-06 2011-08-11 Uhde Gmbh Desulfurization process
CN201944861U (en) 2010-12-06 2011-08-24 山东三维石化工程股份有限公司 Multifunctional tail gas incinerator for sulfur recovery unit
CN101670231B (en) 2009-07-23 2011-08-24 何金整 Device and process for converting calcium process desulfurization into temperature difference crystallizing ammonia process desulfurization
CN201949808U (en) 2011-01-12 2011-08-31 江苏新世纪江南环保有限公司 Flue gas desulfurization device for realizing online oil and dust separation
CN102205202A (en) 2010-03-29 2011-10-05 北京丰汉工程咨询有限公司 Processing method for acid gas containing H2S
US20110243822A1 (en) 2010-03-31 2011-10-06 Airborne Technologies Inc. Flue gas clean up methods
CN102381685A (en) 2010-08-25 2012-03-21 中国石油化工股份有限公司 Degassing technique for liquid sulfur
CN102380305A (en) 2011-09-30 2012-03-21 合肥宁垣工程技术有限责任公司 Technology and apparatus for desulphurizing acidic gas
CN102381686A (en) 2011-07-29 2012-03-21 山东三维石化工程股份有限公司 Treatment process of high-ammonia and low-sulfur gas
US8178070B2 (en) 2007-06-21 2012-05-15 Fluor Technologies Corporation Air demand feedback control systems and methods for sulfur recovery units
CN102451604A (en) 2010-10-18 2012-05-16 袁俊海 Two-stage Claus and SCOT tail gas treatment process
CN101791517B (en) 2010-04-08 2012-05-23 北京至清时光环保工程技术有限公司 Method for recycling sulfur from acid gases containing hydrogen sulfide
US8206669B2 (en) 2010-07-27 2012-06-26 Air Products And Chemicals, Inc. Method and apparatus for treating a sour gas
CN101574614B (en) 2008-05-07 2012-07-18 北京丰汉工程咨询有限公司 Desulphurization method for acid gas
CN101637685B (en) 2009-08-24 2012-07-18 成都德美工程技术有限公司 Comprehensive treatment method of sulfur-containing flue gas
CN101456540B (en) 2007-12-14 2012-07-25 山东三维石化工程股份有限公司 Liquid sulfur pool high temperature resistant and corrosion proof structure
CN102631827A (en) 2012-04-11 2012-08-15 山东三维石化工程股份有限公司 Zero-emission sulfur recovery technology combined with low-temperature methanol washing acid gas treatment
CN202460420U (en) 2012-01-04 2012-10-03 江苏新世纪江南环保股份有限公司 Breathing bucket device for purifying tail gas exhausted by storage tank
CN202460438U (en) 2012-01-04 2012-10-03 江苏新世纪江南环保股份有限公司 Desulfurizing liquid oxidation and purification combined device
CN202460375U (en) 2012-01-04 2012-10-03 江苏新世纪江南环保股份有限公司 Desulfurated dust-laden tail gas washing and recovering device
CN101530727B (en) 2009-03-13 2012-11-07 北京航星世纪科技发展有限公司 Desulfurization process containing H<2>S acidic gas
WO2012152919A1 (en) 2011-05-11 2012-11-15 Hofung Sulphur Technology Limited A method for treating a sulfur-containing gas stream
CN102211762B (en) 2010-04-06 2012-11-21 山东三维石化工程股份有限公司 Method for preparing sulfur and processing tail gas by taking ammonium bisulfite as intermediate
CN101955828B (en) 2010-09-07 2012-11-21 山东三维石化工程股份有限公司 Method for removing hydrogen sulfide from natural gas
CN101972592B (en) 2010-09-08 2012-12-05 江苏新世纪江南环保股份有限公司 Process for removing smoke dust by wet ammonia flue gas desulphurization and device thereof
CN101934191B (en) 2010-09-06 2013-01-09 江苏新世纪江南环保股份有限公司 Method for desulfurizing and denitrating smoke simultaneously through ammonia method
CN102049186B (en) 2009-10-27 2013-01-23 中国石油化工股份有限公司 Method for desulfurizing high-concentration flue gas
US8361432B2 (en) 2010-12-08 2013-01-29 Fluor Enterprises, Inc. Reactor, a retained catalyst structure, and a method for improving decomposition of polysulfides and removal of hydrogen sulfide in liquid sulfur
CN202754802U (en) 2012-07-23 2013-02-27 重庆万盛煤化有限责任公司 Sulphur coal claus sulfur recovery system
CN202751942U (en) 2012-08-08 2013-02-27 上海河图工程股份有限公司 Sulphur tail gas absorption and purification combined device
CN202829575U (en) 2012-08-06 2013-03-27 中国石油化工股份有限公司 Sulfur recycling device
CN101418246B (en) 2008-12-05 2013-04-03 华陆工程科技有限责任公司 Low temperature methanol washing integrated Claus sulfur recovery system and process
CN202912691U (en) 2012-06-15 2013-05-01 洛阳瑞泽石化工程有限公司 Liquid sulfur collector for sulfur recovery device
CN202924730U (en) 2012-09-05 2013-05-08 山东三维石化工程股份有限公司 Inner floating ball type sulfur sealing tank
US8444943B2 (en) 2010-04-30 2013-05-21 Black & Veatch Corporation Methods and apparatus for sulfur recovery from acid gases
CN202953829U (en) 2012-12-11 2013-05-29 内蒙古大唐国际克什克腾煤制天然气有限责任公司 Acid gas desulfurizing device
CN103212281A (en) 2013-03-29 2013-07-24 江苏中显集团有限公司 Smoke desulfurization and denitrification integration method and special device thereof
CN102381687B (en) 2011-02-12 2013-08-14 李金山 Method for preparing acid by using sulfur containing waste material and wet method desulphurization process containing method thereof
CN203159221U (en) 2013-03-19 2013-08-28 镇海石化工程股份有限公司 Supporting structure for sulfur reactor
US8545793B2 (en) 2010-03-22 2013-10-01 Thyssenkrupp Uhde Gmbh Device and method for condensing, separating, and storing liquid sulfur in a Claus plant
CN203264545U (en) 2013-04-25 2013-11-06 江苏新世纪江南环保股份有限公司 Ammonia escape preventing device used in flue gas ammonia desulphurization and denitrification process
CN203291675U (en) 2013-06-19 2013-11-20 江苏新世纪江南环保股份有限公司 Flue gas desulfurization absorber with aerosol controlling function
CN103418223A (en) 2013-07-26 2013-12-04 新汶矿业集团有限责任公司 Comprehensive desulphurization technology in coal chemical industry
CN203329558U (en) 2013-06-20 2013-12-11 江苏新世纪江南环保股份有限公司 Wet-type flue gas desulfurization tail gas repurifying device
CN102489140B (en) 2012-01-04 2013-12-25 江苏新世纪江南环保股份有限公司 Flue gas desulphurization and denitration reactant integrated supply method and apparatus
US20140050643A1 (en) * 2010-06-23 2014-02-20 Baoquan Zhang Flur-Gas purification and reclamation system and method thereof
CN103721553A (en) 2014-01-07 2014-04-16 江苏新世纪江南环保股份有限公司 Method for efficiently removing acid gas sulfide by ammonia process desulfurization technique
CN103768919A (en) 2012-10-26 2014-05-07 中国石油化工股份有限公司 Flue gas desulfurization and denitrification process method
CN203612955U (en) 2013-09-26 2014-05-28 上海河图工程股份有限公司 Liquid sulfur degassing device
CN102942162B (en) 2012-12-06 2014-08-13 山东三维石化工程股份有限公司 Liquid-phase treatment process of tail gas from sulfur recovery
CN203781842U (en) 2014-04-18 2014-08-20 中石化南京工程有限公司 New sulfur recovery device
CN102910593B (en) 2012-10-30 2014-09-17 美景（北京）环保科技有限公司 System and method for treating waste acid gas
CN103204477B (en) 2013-04-25 2014-10-15 山东三维石化工程股份有限公司 Liquid sulphur collecting method for sulfur recovery
CN102847431B (en) 2012-08-14 2014-10-22 北京丰汉工程咨询有限公司 Method for treating claus technical tail gas
US8871176B2 (en) 2012-09-19 2014-10-28 China Petroleum & Chemical Corporation Process for reducing sulfur emission of sulfur plant
CN103446859B (en) 2013-09-12 2014-10-29 中国海洋石油总公司 Treatment method of acid gases in coal-made natural gas
CN104138713A (en) 2013-05-10 2014-11-12 杭州林达化工技术工程有限公司 Method, device and reactor for recovery of sulfur from acidic gas
CN103301732B (en) 2013-06-20 2015-01-21 义马煤业集团煤生化高科技工程有限公司 Device and process for recycling and treating hydrogen sulfide-containing chemical acid waste gas
CN103041679B (en) 2013-01-15 2015-02-04 美景（北京）环保科技有限公司 Waste gas treatment system of acid gas containing ammonia
CN204134465U (en) 2014-10-08 2015-02-04 美景（北京）环保科技有限公司 A kind of Acidic Gas Treating system based on the ammonia process of desulfurization
CN204151066U (en) 2014-09-18 2015-02-11 中石化南京工程有限公司 A kind of sulphur recovery new device processing alkylation spent acid
CN104368231A (en) 2014-10-10 2015-02-25 江苏新世纪江南环保股份有限公司 Method for controlling chlorine / fluorine content in flue gas desulfurization absorption liquid
CN103301736B (en) 2012-11-15 2015-02-25 江苏新世纪江南环保股份有限公司 Ammonia escape prevention device in desulfurization and denitrification of flue gas by using ammonia process
US8968691B2 (en) * 2010-08-03 2015-03-03 Hitachi, Ltd. Treatment method and treatment facilities of exhaust gas
CN102923670B (en) 2012-11-22 2015-03-04 山东三维石化工程股份有限公司 Liquid sulfur degasification process
CN102895870B (en) 2012-09-28 2015-03-04 美景（北京）环保科技有限公司 Treatment system and treatment method for removing hydrogen sulfide from acid gas
CN204198421U (en) 2014-11-14 2015-03-11 镇海石化工程股份有限公司 A kind of molten sulfur pond gas recovery system
CN204233957U (en) 2014-10-30 2015-04-01 中国石油化工股份有限公司 A kind of novel sulfurizedization hydrogen waste gas pollution control and treatment system
CN103223292B (en) 2013-04-15 2015-04-22 江苏新世纪江南环保股份有限公司 Ammonia process flue gas treatment method for acidic tail gas and device
CN104555939A (en) 2013-10-15 2015-04-29 中国石油化工股份有限公司 Purified gas treatment process of sulfur recovery device
CN103112831B (en) 2013-02-26 2015-05-13 镇海石化工程股份有限公司 Liquid sulphur degassing device and liquid sulphur degassing method
CN204352660U (en) 2014-04-16 2015-05-27 南京新世纪江南环保科技发展有限公司 The special demister of a kind of high-efficiency ammonia desulfurization
CN103301705B (en) 2013-06-06 2015-08-19 江苏新世纪江南环保股份有限公司 A kind of desulfurization fume fine particulates control device and method
CN103482583B (en) 2013-09-10 2015-09-02 山东三维石化工程股份有限公司青岛分公司 SWSR-1 sulfur recovery technology
CN104927894A (en) 2015-05-18 2015-09-23 江苏新世纪江南环保股份有限公司 Diesel oxidation ammonia desulfurization method
CN104923046A (en) 2015-05-20 2015-09-23 江苏新世纪江南环保股份有限公司 Coke oven flue gas desulfurization, denitration and waste heat recovery integrated method
CN104946296A (en) 2015-05-18 2015-09-30 江苏新世纪江南环保股份有限公司 Gasoline-oxidation ammonia-process desulfurization method
CN104941423A (en) 2015-05-20 2015-09-30 江苏新世纪江南环保股份有限公司 Ammonia desulfurization and denitrification dedusting method and device utilizing catalytic cracking regeneration flue gas
CN105110819A (en) 2015-07-22 2015-12-02 江苏新世纪江南环保股份有限公司 Method used for producing sulfur-based urea compound fertilizer from ammonia desulphurization by-products
CN105126573A (en) 2015-07-22 2015-12-09 江苏新世纪江南环保股份有限公司 Integrated ammonia-process desulfurization method of various acidic gases in oil refining device
CN103463949B (en) 2013-08-08 2015-12-23 江苏新世纪江南环保股份有限公司 The method and apparatus of a kind of flue gas desulphurization system process greasy dirt, flue dust
CN104353258B (en) 2014-11-18 2016-01-06 镇海石化工程股份有限公司 Subtract top pumped vacuum systems and technique
US9289720B2 (en) * 2012-05-31 2016-03-22 Mitsubishi Hitachi Power Systems, Ltd. System and method for treating mercury in flue gas
CN104249995B (en) 2013-06-25 2016-04-13 中国石油化工股份有限公司 Reduce sulfur recovery facility SO 2the method of emission concentration
CN205235588U (en) 2015-12-17 2016-05-18 南京新世纪江南环保科技发展有限公司 Defroster mounting
CN205245200U (en) 2015-12-29 2016-05-18 南京新世纪江南环保科技发展有限公司 Chimney water smoke connects and draws dish
CN205252722U (en) 2015-12-17 2016-05-25 南京新世纪江南环保科技发展有限公司 Defroster subassembly
CN205252721U (en) 2015-12-17 2016-05-25 南京新世纪江南环保科技发展有限公司 Double -deck defroster subassembly of buckle blade
CN205262780U (en) 2015-12-29 2016-05-25 南京新世纪江南环保科技发展有限公司 Can sealed thief hatch
CN205252720U (en) 2015-12-17 2016-05-25 南京新世纪江南环保科技发展有限公司 House rigde mounting structure of defroster module
CN103822217B (en) 2014-02-14 2016-06-01 江苏新世纪江南环保股份有限公司 A kind of sour gas pretreatment technology
US9370745B2 (en) 2013-04-24 2016-06-21 Jiangsu New Century Jiangnan Environmental Protection Co., Ltd Flue gas-treating method and apparatus for treating acidic tail gas by using ammonia process
US9381461B2 (en) * 2010-05-31 2016-07-05 Mitsubishi Heavy Industries, Ltd. Air pollution control system and method
CN105757688A (en) 2016-03-23 2016-07-13 江苏新世纪江南环保股份有限公司 Method and system for treating VOCs gas in sewage treatment plant
CN105841168A (en) 2016-03-23 2016-08-10 江苏新世纪江南环保股份有限公司 Integrated treatment method for malodorous VOCs gas of refining devices
CN104555940B (en) 2013-10-15 2016-08-17 中国石油化工股份有限公司 Reduce the recovery technology of sulfur of sulfur dioxide (SO2) emissions
CN205549846U (en) 2015-12-17 2016-09-07 南京新世纪江南环保科技发展有限公司 Double -deck defroster subassembly
CN104524948B (en) 2015-01-08 2016-09-07 江苏新世纪江南环保股份有限公司 A kind of ultrasonic wave desulphurizing and dust-removing integral minimum discharge method
CN205562498U (en) 2015-12-15 2016-09-07 南京新世纪江南环保科技发展有限公司 Sealed pH meter interface
CN103939918B (en) 2014-04-11 2017-01-25 江苏新世纪江南环保股份有限公司 Incineration method for acid gas and liquid purification
CN103521060B (en) 2012-07-04 2017-01-25 江苏新世纪江南环保股份有限公司 Method for desulfurization of sulfur recovery tail gas by using boiler flue gas ammonia method
CN104208992B (en) 2014-09-17 2017-02-01 宁波市化工研究设计院有限公司 Method for desulfurizing acid gas containing hydrogen sulfide and recycling sulfur
CN104258713B (en) 2014-10-08 2017-02-15 美景（北京）环保科技有限公司 Acid gas treatment system and method based on ammonia-process desulfurization
US20170066652A1 (en) * 2009-01-21 2017-03-09 Res Usa, Llc System and Method for Dual Fluidized Bed Gasification
CN104528659B (en) 2014-12-17 2017-04-12 田晓良 Sulfur recycling process for circularly treating low-concentration acidy gas by utilizing liquid sulfur
US9700839B2 (en) * 2013-02-25 2017-07-11 Mitsubishi Hitachi Power Systems, Ltd. Air pollution control system and air pollution control method
US20170312684A1 (en) * 2013-04-16 2017-11-02 Carbonxt, Inc. Systems and methods for post combustion mercury control using sorbent injection and wet scrubbing

Family Cites Families (33)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4250160A (en) 1977-08-15 1981-02-10 Exxon Research & Engineering Co. Production of ammonium sulfate
US5362458A (en) 1993-03-22 1994-11-08 General Electric Environmental Services, Incorporated Process for the simultaneous absorption of sulfur oxides and production of ammonium sulfate
US6991771B2 (en) 1996-10-09 2006-01-31 Powerspan Corp. NOx, Hg, and SO2 removal using ammonia
US6221325B1 (en) 1998-09-08 2001-04-24 Marsulex Environmental Technologies, Llc Process for controlling ammonia slip in the reduction of sulfur dioxide emission
CN1268389A (en) * 1999-03-31 2000-10-04 湘潭市南方高新技术研究院环保工程研究所 Coal-fired flue-gas dust-removing and desulfurization process
CN1096285C (en) 2000-07-17 2002-12-18 史汉祥 Special device for processing so2 containing fume
US6936231B2 (en) 2001-12-06 2005-08-30 Powerspan Corp. NOx, Hg, and SO2 removal using ammonia
CN1139422C (en) 2001-12-30 2004-02-25 国家环境保护总局华南环境科学研究所 Wet urea additive process for simultanously desulfurizing and denitrification
CN1178735C (en) 2002-09-09 2004-12-08 华东理工大学 Removing and recovering process and device for SO2 in flue gas
CN2778373Y (en) 2005-04-22 2006-05-10 胡恩龙 Ejection sieve plate absorber
CN101352642A (en) 2007-07-25 2009-01-28 上海智方环保工程有限公司 Flue gas desulfurization system by lime-sodium alkaline method
CN201643982U (en) * 2009-10-27 2010-11-24 中国石油化工股份有限公司 FCC flue gas denitration catalytic reactor
CN101745303A (en) 2009-12-30 2010-06-23 王建敏 Improved smoke removal purifier
CN102309920B (en) * 2010-07-07 2014-01-01 中国石油化工股份有限公司 Method for removing NOx and SOx from fluid catalytic cracking (FCC) flue gas
CN101972582A (en) 2010-11-05 2011-02-16 北京信诺海博石化科技发展有限公司 Switching method of pressure swing adsorption device for treating non-condensable gas
CN201880482U (en) 2010-11-19 2011-06-29 上海弗卡斯环保工程有限公司 Stepped spray tower for desulfurization by ammonia method
CN102000490B (en) 2010-11-25 2012-07-25 东南大学 Control method for aerosol in flue gas desulfurization by utilizing ammonia method and master desulfurizing tower
CN202122902U (en) * 2011-07-06 2012-01-25 青岛宏泰翔环保工程有限公司 New high-efficiency device for denitration and desulfuration at low temperature
CN102423597B (en) 2011-10-14 2014-06-11 华南理工大学 Intelligent anti-blocking demister used for wet flue gas desulfurization
JP6223654B2 (en) 2011-10-31 2017-11-01 三菱日立パワーシステムズ株式会社 Flue gas desulfurization equipment
CN202538627U (en) 2011-12-27 2012-11-21 合肥宁垣工程技术有限责任公司 Device for removing desulfurization and denitration aerosol
CN202725003U (en) 2012-06-28 2013-02-13 北京中科创新园环境技术有限公司 Compound type multifunctional ammonia desulphurization device
CN103041678B (en) * 2012-12-21 2015-02-11 浙江天蓝环保技术股份有限公司 Ammonia flue gas desulfuration and denitration combined process and device
US8715600B1 (en) 2013-05-16 2014-05-06 Babcock & Wilcox Power Generation Group, Inc. Circulating dry scrubber
CN104279995A (en) 2014-10-28 2015-01-14 重庆御捷汽车部件有限公司 Parking cable stroke change amount measuring device
CN204352726U (en) * 2014-12-26 2015-05-27 浙江西子联合工程有限公司 Water coal-pulp smoke cleaning system
CN105056746A (en) 2015-08-18 2015-11-18 江苏一同环保工程技术有限公司 Method for realizing boiler flue gas integrated distributed desulfurization and denitrification process
CN105032145A (en) * 2015-08-18 2015-11-11 江苏一同环保工程技术有限公司 Boiler flue gas integration distributing type SOx/NOx control device
CN205815447U (en) * 2016-05-05 2016-12-21 济南冶金化工设备有限公司 The double ammonia process integration desulfurization denitration system of coking flue gas two-part
CN108144428A (en) 2017-03-15 2018-06-12 江苏新世纪江南环保股份有限公司 A kind of method and device of ammonia process efficient removal gas sulphur oxide and dirt
CN107213769B (en) 2017-05-25 2019-09-20 江苏新世纪江南环保股份有限公司 A kind of ammonia method desulfurizing method and device of locellus ammonification
CN107213785B (en) * 2017-05-25 2020-08-07 江苏新世纪江南环保股份有限公司 Method and device for denitration, desulfurization and dust removal of FCC (fluid catalytic cracking) tail gas by ammonia process
MX2017008528A (en) 2017-06-14 2019-02-08 Jiangnan Environmental Prot Group Inc Automatic ammonia-adding system and method for ammonia-based desulfurization device.

Patent Citations (206)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2810627A (en) 1953-02-26 1957-10-22 Texas Gulf Sulphur Co Recovery of sulfur dioxide from gases and production of ammonium sulphate
US3752877A (en) 1969-08-27 1973-08-14 Parsons Co Ralph M Recovery of sulfur compounds from tail gases
US3970740A (en) * 1973-06-13 1976-07-20 Exxon Research And Engineering Company Wet gas scrubbing process
US3983217A (en) 1973-09-26 1976-09-28 Kurashiki Boseki Kabushiki Kaisha Method for removing sulfur dioxide from waste gases
US4294590A (en) 1978-11-09 1981-10-13 Linde Aktiengesellschaft Removal of undesired gaseous components from hot waste gases
US4378977A (en) 1978-11-09 1983-04-05 Linde Aktiengesellschaft Removal of undesired gaseous components from hot waste gases
US4238317A (en) * 1979-08-20 1980-12-09 Standard Oil Company (Indiana) Catalytic cracking with reduced emission of noxious gases
US4324776A (en) 1980-12-08 1982-04-13 General Electric Company Mid-temperature H2 S removal process
EP0165609B1 (en) 1984-06-20 1989-09-06 Air Products And Chemicals, Inc. Temperature moderation of an oxygen enriched claus sulfur plant
US4552747A (en) 1984-06-20 1985-11-12 Gaa Engineered Systems, Inc. Temperature moderation of an oxygen enriched Claus sulfur plant
US4690807A (en) 1985-08-15 1987-09-01 General Electric Environmental Services, Inc. Process for the simultaneous absorption of sulfur oxides and production of ammonium sulfate
EP0212523A2 (en) 1985-08-15 1987-03-04 General Electric Company Process for the simultaneous absorption of sulfur oxides and production of ammonium sulfate
DE3733319A1 (en) 1987-10-02 1989-04-13 Krupp Koppers Gmbh Process for removing sulphur dioxide from flue gases
US5106607A (en) 1987-12-23 1992-04-21 Rhone-Poulenc Chimie Multilobar catalysts for the conversion of sulfur containing gaseous effluents
US5019361A (en) 1988-11-09 1991-05-28 Union Carbide Canada Limited Removal and recovery of sulphur dioxide from gas streams
US5632967A (en) 1995-09-19 1997-05-27 Goar, Allison & Associates, Inc. Process for the high pressure degassing of hydrogen sulfide from liquid sulfur
US6444185B1 (en) 1995-11-03 2002-09-03 Elf Exploration Production Process for recovering as sulfur the compounds H2S, SO2, COS and/or CS2 in a tail gas from a sulfur plant
US6508998B1 (en) 1996-10-28 2003-01-21 Gaa Engineered Systems, Inc. Temperature moderation of an oxygen enriched claus sulfur plant using an ejector
US6139807A (en) 1997-07-19 2000-10-31 Lurgi Lentjes Bischoff Gmbh Apparatus for removing SO2 from flue gases and for producing ammonium sulfate solution
US6063352A (en) 1997-07-19 2000-05-16 Lurgi Lentjes Bischoff Gmbh Method of removing sulfur dioxide from flue gases, especially power plant flue gases and flue gases from garbage incinerator plants
US6203598B1 (en) * 1998-02-23 2001-03-20 Mitsubishi Heavy Industries, Ltd. Flue gas treating process and system
US6066304A (en) * 1998-08-06 2000-05-23 Delores Pircon Process for removing sulfur dioxide out of a gas
US6776974B1 (en) 1999-10-22 2004-08-17 Monsanto Enviro-Chem Systems, Inc. Process for the production of sulfur
US6752975B2 (en) * 2000-07-31 2004-06-22 Showa Denko K.K. Combustion exhaust gas treatment process and treatment apparatus
US6616908B2 (en) 2000-08-31 2003-09-09 The Boc Group Plc Treatment of a gas stream containing hydrogen sulphide
US6569398B2 (en) 2001-04-30 2003-05-27 Gaa Engineered Systems, Inc. Method for treating hydrogen sulfide-containing waste gases
CN1164480C (en) 2001-09-26 2004-09-01 南化集团研究院 Combined production of high concentration sulphuric acid by using acid gas containing hydrogen sulfide and sulphur
CN1251965C (en) 2002-06-25 2006-04-19 南化集团研究院 Preparation of high-concntration surlfuric acid using hydrogen sulfide contained acidic gas
WO2005007505A1 (en) 2003-07-22 2005-01-27 Knutsen Oas Shipping As Method and device for protecting a vessel’s loading space from excess pressure
CN1321723C (en) 2003-09-17 2007-06-20 镇江市江南环保设备研究所 Method of separating and recovering sulfur dioxide in smoke using ammonia method
CN1283346C (en) 2003-09-17 2006-11-08 镇江市江南环保设备研究所 Fuel coal smoke low oxidation rate desulfur method
CN2640584Y (en) 2003-09-17 2004-09-15 镇江市江南环保设备研究所 Integrated equipment for desulfurizing and discharging smoke
CN2668235Y (en) 2003-09-19 2005-01-05 镇江市江南环保设备研究所 High-speed smoke gas desulfurizing tower
CN2640585Y (en) 2003-09-19 2004-09-15 镇江市江南环保设备研究所 Reinforced desulfurizing tower for smoke
US7635408B2 (en) 2004-01-20 2009-12-22 Fluor Technologies Corporation Methods and configurations for acid gas enrichment
US7351392B2 (en) 2004-03-03 2008-04-01 Shell Oil Company Process for the high recovery efficiency of sulfur from an acid gas stream
US7754471B2 (en) 2004-03-03 2010-07-13 Shell Oil Company Process for the high recovery efficiency of sulfur from an acid gas stream
US20090004070A1 (en) 2004-04-22 2009-01-01 Fluor Technologies Corporation Configurations and Methods for Effluent Gas Treatment
US7648692B2 (en) 2004-04-22 2010-01-19 Fluor Technologies Corporation COS-Claus configurations and methods
WO2005113429A1 (en) 2004-04-22 2005-12-01 Fluor Technologies Corporation Configurations and methods for effluent gas treatment
US20070248518A1 (en) 2004-06-08 2007-10-25 Kirea Institute Of Science And Technology Desulfurizartion for Simultaneous Removal of Hydrogen Sulfide and Sulfur Dioxide
US7910077B2 (en) 2004-11-09 2011-03-22 Fluor Technologies Corporation Configurations and methods for SOx removal in oxygen-containing gases
CN2746973Y (en) 2004-12-07 2005-12-21 镇江市江南环保设备研究所 Demister of nitrogen method desulfurization tower
CN2772609Y (en) 2004-12-07 2006-04-19 镇江市江南环保设备研究所 Oxidizing tower of smoke ammonia devulcanizer
CN2754711Y (en) 2004-12-07 2006-02-01 镇江市江南环保设备研究所 Smoke desulfurized filling tower from ammonia method
CN2746971Y (en) 2004-12-07 2005-12-21 镇江市江南环保设备研究所 Desulfurization and denitration integrated flue-gas purification tower
CN2746972Y (en) 2004-12-07 2005-12-21 镇江市江南环保设备研究所 Multi-functional and combination type desulfurization tower
WO2006113935A2 (en) 2005-04-20 2006-10-26 Fluor Technologies Corporation Configurations and methods for claus plant operation with variable sulfur content
US7879135B2 (en) 2005-04-20 2011-02-01 Fluor Technologies Corporation Configurations and methods for claus plant operation with variable sulfur content
CN100428979C (en) 2005-06-28 2008-10-29 江苏世纪江南环保有限公司 Ammonia desulfurizing process and apparatus with crystallization inside tower
CN2799059Y (en) 2005-06-28 2006-07-26 镇江市江南环保设备研究所 Inside-crystallizing ammonia-processed desulfurization tower
CN2799060Y (en) 2005-06-28 2006-07-26 镇江市江南环保设备研究所 Empty tower type ammonia processed desulfurization tower
CN100395006C (en) 2005-06-28 2008-06-18 江苏世纪江南环保有限公司 Void tower type ammonia desulfurizing process and apparatus
CN100460045C (en) 2006-05-31 2009-02-11 中国石油化工股份有限公司 Process for disposing SOx in discharge gas
CN101108301A (en) 2006-07-21 2008-01-23 中国石油化工股份有限公司 Flue gas desulfurizing method and apparatus
US20080050299A1 (en) * 2006-08-25 2008-02-28 Bedell Michael W Wet gas scrubbing process
US7569198B2 (en) * 2006-08-25 2009-08-04 Exxonmobil Research & Engineering Company Wet gas scrubbing process
CN100475313C (en) 2007-02-13 2009-04-08 西安中宇软件科技有限责任公司 Device for the recovery and diffluence of sulfur dioxide and the system and method thereof
CN101274204B (en) 2007-03-28 2011-06-22 成都华西化工研究所 Absorbing agent for removing and recovering sulfur dioxide from gaseous mixture
CN100588608C (en) 2007-04-30 2010-02-10 中国石油集团工程设计有限责任公司 The improvement low-temperature Claus sulfur recovery method
CN201030298Y (en) 2007-05-21 2008-03-05 江苏晟宜环保科技有限公司 One-segment type low-sulfur oxidizing catalyst reactor
US8178070B2 (en) 2007-06-21 2012-05-15 Fluor Technologies Corporation Air demand feedback control systems and methods for sulfur recovery units
CN201052456Y (en) 2007-07-02 2008-04-30 江苏晟宜环保科技有限公司 Wrapped-tube catalytic oxidation reactor
CN101085410A (en) 2007-07-16 2007-12-12 娄爱娟 Method and device for reclaiming sulfur dioxide from countercurrent flue gas
CN201109711Y (en) 2007-10-31 2008-09-03 镇海石化工程有限责任公司 Pool for storing underground liquid sulphur
CN201129965Y (en) 2007-11-20 2008-10-08 镇海石化工程有限责任公司 Sulfur condenser for sulfur recovery
CN201132102Y (en) 2007-12-11 2008-10-15 镇海石化工程有限责任公司 Ammine-burning device for recovering sulfur
CN101274196B (en) 2007-12-11 2010-12-08 镇海石化工程有限责任公司 Desulphurization method of amine liquid with high removal rate of hydrogen sulfide
CN101456540B (en) 2007-12-14 2012-07-25 山东三维石化工程股份有限公司 Liquid sulfur pool high temperature resistant and corrosion proof structure
CN101182926B (en) 2007-12-14 2011-01-26 镇海石化工程有限责任公司 Stove-fuel flow online control device and method thereof
CN101274750B (en) 2007-12-29 2010-06-30 江苏晟宜环保科技有限公司 Tail gas-recycled sulfur recovery method
CN201179415Y (en) 2008-02-14 2009-01-14 娄爱娟 Flue gas desulfurization purification column
CN101575103A (en) 2008-05-07 2009-11-11 北京丰汉工程咨询有限公司 Method for processing ammonium sulfate in acid gas desulfurization process
CN101576261B (en) 2008-05-07 2011-05-11 北京丰汉工程咨询有限公司 Combustion and catalytic reduction method for acid gas
CN101574614B (en) 2008-05-07 2012-07-18 北京丰汉工程咨询有限公司 Desulphurization method for acid gas
CN201231130Y (en) 2008-07-29 2009-05-06 中冶集团北京冶金设备研究设计总院 Flue gas desulfurization device for producing ammonia sulfate fertilizer
CN101642629A (en) 2008-08-08 2010-02-10 山东三维石化工程股份有限公司 Method for controlling amine solvent regeneration system
US20110195008A1 (en) 2008-10-06 2011-08-11 Uhde Gmbh Desulfurization process
CN201320447Y (en) 2008-10-27 2009-10-07 江苏新世纪江南环保有限公司 Integrated smoke purification device for desulphurization and denitration
CN201333376Y (en) 2008-11-14 2009-10-28 江苏新世纪江南环保有限公司 Flue gas desulfurization and denitration purifying device
CN101422693A (en) 2008-11-24 2009-05-06 贵州开磷（集团）有限责任公司 Sulphuric acid tail-gas deep desulfurization method
CN101418246B (en) 2008-12-05 2013-04-03 华陆工程科技有限责任公司 Low temperature methanol washing integrated Claus sulfur recovery system and process
CN101456541B (en) 2008-12-16 2011-05-25 山东三维石化工程股份有限公司 Selecting and packing method of catalyst for sulphur preparation
US20170066652A1 (en) * 2009-01-21 2017-03-09 Res Usa, Llc System and Method for Dual Fluidized Bed Gasification
CN201380037Y (en) 2009-01-23 2010-01-13 江苏新世纪江南环保有限公司 Flue-gas cleaner with functions of desulphurization, denitration, concentration and crystal
CN201380038Y (en) 2009-01-23 2010-01-13 江苏新世纪江南环保有限公司 Grid-type wet desulphurization device
CN201380040Y (en) 2009-01-23 2010-01-13 江苏新世纪江南环保有限公司 Combined device for purifying coal-fired flue gas
CN201380039Y (en) 2009-01-23 2010-01-13 江苏新世纪江南环保有限公司 Double-tower flue gas desulphurization device
CN201423237Y (en) 2009-01-23 2010-03-17 江苏新世纪江南环保有限公司 Ammonia bubble crystallized flue gas desulfurizing device
CN101530727B (en) 2009-03-13 2012-11-07 北京航星世纪科技发展有限公司 Desulfurization process containing H<2>S acidic gas
CN101519192B (en) 2009-03-27 2011-02-09 成都赛普瑞兴科技有限公司 Low temperature Claus sulfur recovery process and device therefor
CN101524620A (en) 2009-04-13 2009-09-09 山西晋丰环保工程设计有限公司 Segment-based ammonia flue gas desulfurization process and device thereof
CN101579600B (en) 2009-05-04 2011-04-20 何金整 Ammonia desulfurization technology and device utilizing high potential energy
CN101579602B (en) 2009-06-12 2011-05-04 山西晋丰环保工程设计有限公司 Energy-saving and high-quality ammonia desulphurization process for ammonia sulfate recovery
CN101585511A (en) 2009-06-25 2009-11-25 中国石油化工集团公司 Sulfur recycling technique
CN101670231B (en) 2009-07-23 2011-08-24 何金整 Device and process for converting calcium process desulfurization into temperature difference crystallizing ammonia process desulfurization
CN201492952U (en) 2009-08-12 2010-06-02 江苏新世纪江南环保有限公司 Flue gas heat source heat pipe-type evaporation device of byproduct in ammonia process of flue gas desulfurization
CN201537456U (en) 2009-08-12 2010-08-04 江苏新世纪江南环保有限公司 Flue gas heat exchange type evaporator of flue gas desulfurization side product by ammonia method
CN101637685B (en) 2009-08-24 2012-07-18 成都德美工程技术有限公司 Comprehensive treatment method of sulfur-containing flue gas
CN102049186B (en) 2009-10-27 2013-01-23 中国石油化工股份有限公司 Method for desulfurizing high-concentration flue gas
CN201529488U (en) 2009-10-30 2010-07-21 江苏新世纪江南环保有限公司 Gas ammonia washing combined sintering smoke desulphurization device
CN201529487U (en) 2009-10-30 2010-07-21 江苏新世纪江南环保有限公司 Gas cleaning device for liquid phase catalysis de-nitration
US8545793B2 (en) 2010-03-22 2013-10-01 Thyssenkrupp Uhde Gmbh Device and method for condensing, separating, and storing liquid sulfur in a Claus plant
CN102205202A (en) 2010-03-29 2011-10-05 北京丰汉工程咨询有限公司 Processing method for acid gas containing H2S
US20110243822A1 (en) 2010-03-31 2011-10-06 Airborne Technologies Inc. Flue gas clean up methods
CN102211762B (en) 2010-04-06 2012-11-21 山东三维石化工程股份有限公司 Method for preparing sulfur and processing tail gas by taking ammonium bisulfite as intermediate
CN101791517B (en) 2010-04-08 2012-05-23 北京至清时光环保工程技术有限公司 Method for recycling sulfur from acid gases containing hydrogen sulfide
US8444943B2 (en) 2010-04-30 2013-05-21 Black & Veatch Corporation Methods and apparatus for sulfur recovery from acid gases
US9381461B2 (en) * 2010-05-31 2016-07-05 Mitsubishi Heavy Industries, Ltd. Air pollution control system and method
US20150104365A1 (en) * 2010-06-23 2015-04-16 Baoquan Zhang Flue-Gas Purification and Reclamation System and Method Thereof
US20140050643A1 (en) * 2010-06-23 2014-02-20 Baoquan Zhang Flur-Gas purification and reclamation system and method thereof
US8206669B2 (en) 2010-07-27 2012-06-26 Air Products And Chemicals, Inc. Method and apparatus for treating a sour gas
US8968691B2 (en) * 2010-08-03 2015-03-03 Hitachi, Ltd. Treatment method and treatment facilities of exhaust gas
CN102381685A (en) 2010-08-25 2012-03-21 中国石油化工股份有限公司 Degassing technique for liquid sulfur
CN101934191B (en) 2010-09-06 2013-01-09 江苏新世纪江南环保股份有限公司 Method for desulfurizing and denitrating smoke simultaneously through ammonia method
CN101955828B (en) 2010-09-07 2012-11-21 山东三维石化工程股份有限公司 Method for removing hydrogen sulfide from natural gas
CN101972592B (en) 2010-09-08 2012-12-05 江苏新世纪江南环保股份有限公司 Process for removing smoke dust by wet ammonia flue gas desulphurization and device thereof
CN102451604A (en) 2010-10-18 2012-05-16 袁俊海 Two-stage Claus and SCOT tail gas treatment process
CN102061206A (en) 2010-12-02 2011-05-18 山东三维石化工程股份有限公司 Pressure reduction gas desulfurization method
CN201944861U (en) 2010-12-06 2011-08-24 山东三维石化工程股份有限公司 Multifunctional tail gas incinerator for sulfur recovery unit
CN102012034A (en) 2010-12-06 2011-04-13 山东三维石化工程股份有限公司 Multifunctional exhaust incinerator for sulfur recovery facility
US8361432B2 (en) 2010-12-08 2013-01-29 Fluor Enterprises, Inc. Reactor, a retained catalyst structure, and a method for improving decomposition of polysulfides and removal of hydrogen sulfide in liquid sulfur
CN201912885U (en) 2011-01-06 2011-08-03 江苏新世纪江南环保有限公司 Desulfurizing and impurity removing integrated purifying device for sintering flue gas
CN201912884U (en) 2011-01-06 2011-08-03 江苏新世纪江南环保有限公司 Ammonia desulfurizer with two-level gas distributors
CN201949808U (en) 2011-01-12 2011-08-31 江苏新世纪江南环保有限公司 Flue gas desulfurization device for realizing online oil and dust separation
CN102381687B (en) 2011-02-12 2013-08-14 李金山 Method for preparing acid by using sulfur containing waste material and wet method desulphurization process containing method thereof
WO2012152919A1 (en) 2011-05-11 2012-11-15 Hofung Sulphur Technology Limited A method for treating a sulfur-containing gas stream
CN102381686A (en) 2011-07-29 2012-03-21 山东三维石化工程股份有限公司 Treatment process of high-ammonia and low-sulfur gas
CN102380305A (en) 2011-09-30 2012-03-21 合肥宁垣工程技术有限责任公司 Technology and apparatus for desulphurizing acidic gas
CN202460438U (en) 2012-01-04 2012-10-03 江苏新世纪江南环保股份有限公司 Desulfurizing liquid oxidation and purification combined device
CN202460420U (en) 2012-01-04 2012-10-03 江苏新世纪江南环保股份有限公司 Breathing bucket device for purifying tail gas exhausted by storage tank
CN102489140B (en) 2012-01-04 2013-12-25 江苏新世纪江南环保股份有限公司 Flue gas desulphurization and denitration reactant integrated supply method and apparatus
CN202460375U (en) 2012-01-04 2012-10-03 江苏新世纪江南环保股份有限公司 Desulfurated dust-laden tail gas washing and recovering device
CN102631827A (en) 2012-04-11 2012-08-15 山东三维石化工程股份有限公司 Zero-emission sulfur recovery technology combined with low-temperature methanol washing acid gas treatment
US9289720B2 (en) * 2012-05-31 2016-03-22 Mitsubishi Hitachi Power Systems, Ltd. System and method for treating mercury in flue gas
CN202912691U (en) 2012-06-15 2013-05-01 洛阳瑞泽石化工程有限公司 Liquid sulfur collector for sulfur recovery device
CN103521060B (en) 2012-07-04 2017-01-25 江苏新世纪江南环保股份有限公司 Method for desulfurization of sulfur recovery tail gas by using boiler flue gas ammonia method
CN202754802U (en) 2012-07-23 2013-02-27 重庆万盛煤化有限责任公司 Sulphur coal claus sulfur recovery system
CN202829575U (en) 2012-08-06 2013-03-27 中国石油化工股份有限公司 Sulfur recycling device
CN202751942U (en) 2012-08-08 2013-02-27 上海河图工程股份有限公司 Sulphur tail gas absorption and purification combined device
CN102847431B (en) 2012-08-14 2014-10-22 北京丰汉工程咨询有限公司 Method for treating claus technical tail gas
CN202924730U (en) 2012-09-05 2013-05-08 山东三维石化工程股份有限公司 Inner floating ball type sulfur sealing tank
US8871176B2 (en) 2012-09-19 2014-10-28 China Petroleum & Chemical Corporation Process for reducing sulfur emission of sulfur plant
CN102895870B (en) 2012-09-28 2015-03-04 美景（北京）环保科技有限公司 Treatment system and treatment method for removing hydrogen sulfide from acid gas
CN103768919A (en) 2012-10-26 2014-05-07 中国石油化工股份有限公司 Flue gas desulfurization and denitrification process method
CN102910593B (en) 2012-10-30 2014-09-17 美景（北京）环保科技有限公司 System and method for treating waste acid gas
CN103301736B (en) 2012-11-15 2015-02-25 江苏新世纪江南环保股份有限公司 Ammonia escape prevention device in desulfurization and denitrification of flue gas by using ammonia process
CN102923670B (en) 2012-11-22 2015-03-04 山东三维石化工程股份有限公司 Liquid sulfur degasification process
CN102942162B (en) 2012-12-06 2014-08-13 山东三维石化工程股份有限公司 Liquid-phase treatment process of tail gas from sulfur recovery
CN202953829U (en) 2012-12-11 2013-05-29 内蒙古大唐国际克什克腾煤制天然气有限责任公司 Acid gas desulfurizing device
CN103041679B (en) 2013-01-15 2015-02-04 美景（北京）环保科技有限公司 Waste gas treatment system of acid gas containing ammonia
US9700839B2 (en) * 2013-02-25 2017-07-11 Mitsubishi Hitachi Power Systems, Ltd. Air pollution control system and air pollution control method
CN103112831B (en) 2013-02-26 2015-05-13 镇海石化工程股份有限公司 Liquid sulphur degassing device and liquid sulphur degassing method
CN203159221U (en) 2013-03-19 2013-08-28 镇海石化工程股份有限公司 Supporting structure for sulfur reactor
CN103212281A (en) 2013-03-29 2013-07-24 江苏中显集团有限公司 Smoke desulfurization and denitrification integration method and special device thereof
CN103223292B (en) 2013-04-15 2015-04-22 江苏新世纪江南环保股份有限公司 Ammonia process flue gas treatment method for acidic tail gas and device
US20170312684A1 (en) * 2013-04-16 2017-11-02 Carbonxt, Inc. Systems and methods for post combustion mercury control using sorbent injection and wet scrubbing
US9849420B2 (en) * 2013-04-16 2017-12-26 Carbonxt, Inc. Systems and methods for post combustion mercury control using sorbent injection and wet scrubbing
US9370745B2 (en) 2013-04-24 2016-06-21 Jiangsu New Century Jiangnan Environmental Protection Co., Ltd Flue gas-treating method and apparatus for treating acidic tail gas by using ammonia process
CN203264545U (en) 2013-04-25 2013-11-06 江苏新世纪江南环保股份有限公司 Ammonia escape preventing device used in flue gas ammonia desulphurization and denitrification process
CN103204477B (en) 2013-04-25 2014-10-15 山东三维石化工程股份有限公司 Liquid sulphur collecting method for sulfur recovery
CN104138713A (en) 2013-05-10 2014-11-12 杭州林达化工技术工程有限公司 Method, device and reactor for recovery of sulfur from acidic gas
CN103301705B (en) 2013-06-06 2015-08-19 江苏新世纪江南环保股份有限公司 A kind of desulfurization fume fine particulates control device and method
CN203291675U (en) 2013-06-19 2013-11-20 江苏新世纪江南环保股份有限公司 Flue gas desulfurization absorber with aerosol controlling function
CN203329558U (en) 2013-06-20 2013-12-11 江苏新世纪江南环保股份有限公司 Wet-type flue gas desulfurization tail gas repurifying device
CN103301732B (en) 2013-06-20 2015-01-21 义马煤业集团煤生化高科技工程有限公司 Device and process for recycling and treating hydrogen sulfide-containing chemical acid waste gas
CN104249995B (en) 2013-06-25 2016-04-13 中国石油化工股份有限公司 Reduce sulfur recovery facility SO 2the method of emission concentration
CN103418223A (en) 2013-07-26 2013-12-04 新汶矿业集团有限责任公司 Comprehensive desulphurization technology in coal chemical industry
CN103463949B (en) 2013-08-08 2015-12-23 江苏新世纪江南环保股份有限公司 The method and apparatus of a kind of flue gas desulphurization system process greasy dirt, flue dust
CN103482583B (en) 2013-09-10 2015-09-02 山东三维石化工程股份有限公司青岛分公司 SWSR-1 sulfur recovery technology
CN103446859B (en) 2013-09-12 2014-10-29 中国海洋石油总公司 Treatment method of acid gases in coal-made natural gas
CN203612955U (en) 2013-09-26 2014-05-28 上海河图工程股份有限公司 Liquid sulfur degassing device
CN104555939A (en) 2013-10-15 2015-04-29 中国石油化工股份有限公司 Purified gas treatment process of sulfur recovery device
CN104555940B (en) 2013-10-15 2016-08-17 中国石油化工股份有限公司 Reduce the recovery technology of sulfur of sulfur dioxide (SO2) emissions
CN103721553A (en) 2014-01-07 2014-04-16 江苏新世纪江南环保股份有限公司 Method for efficiently removing acid gas sulfide by ammonia process desulfurization technique
US20150352489A1 (en) 2014-01-07 2015-12-10 Jiangsu New Century Jiangnan Environmental Protection Co., Ltd. Effective removal of acidic sulfide gas using ammonia-based desulfurization
CN103822217B (en) 2014-02-14 2016-06-01 江苏新世纪江南环保股份有限公司 A kind of sour gas pretreatment technology
CN103939918B (en) 2014-04-11 2017-01-25 江苏新世纪江南环保股份有限公司 Incineration method for acid gas and liquid purification
CN204352660U (en) 2014-04-16 2015-05-27 南京新世纪江南环保科技发展有限公司 The special demister of a kind of high-efficiency ammonia desulfurization
CN203781842U (en) 2014-04-18 2014-08-20 中石化南京工程有限公司 New sulfur recovery device
CN104208992B (en) 2014-09-17 2017-02-01 宁波市化工研究设计院有限公司 Method for desulfurizing acid gas containing hydrogen sulfide and recycling sulfur
CN204151066U (en) 2014-09-18 2015-02-11 中石化南京工程有限公司 A kind of sulphur recovery new device processing alkylation spent acid
CN204134465U (en) 2014-10-08 2015-02-04 美景（北京）环保科技有限公司 A kind of Acidic Gas Treating system based on the ammonia process of desulfurization
CN104258713B (en) 2014-10-08 2017-02-15 美景（北京）环保科技有限公司 Acid gas treatment system and method based on ammonia-process desulfurization
CN104368231A (en) 2014-10-10 2015-02-25 江苏新世纪江南环保股份有限公司 Method for controlling chlorine / fluorine content in flue gas desulfurization absorption liquid
CN204233957U (en) 2014-10-30 2015-04-01 中国石油化工股份有限公司 A kind of novel sulfurizedization hydrogen waste gas pollution control and treatment system
CN204198421U (en) 2014-11-14 2015-03-11 镇海石化工程股份有限公司 A kind of molten sulfur pond gas recovery system
CN104353258B (en) 2014-11-18 2016-01-06 镇海石化工程股份有限公司 Subtract top pumped vacuum systems and technique
CN104528659B (en) 2014-12-17 2017-04-12 田晓良 Sulfur recycling process for circularly treating low-concentration acidy gas by utilizing liquid sulfur
CN104524948B (en) 2015-01-08 2016-09-07 江苏新世纪江南环保股份有限公司 A kind of ultrasonic wave desulphurizing and dust-removing integral minimum discharge method
CN104946296A (en) 2015-05-18 2015-09-30 江苏新世纪江南环保股份有限公司 Gasoline-oxidation ammonia-process desulfurization method
CN104927894A (en) 2015-05-18 2015-09-23 江苏新世纪江南环保股份有限公司 Diesel oxidation ammonia desulfurization method
CN104923046A (en) 2015-05-20 2015-09-23 江苏新世纪江南环保股份有限公司 Coke oven flue gas desulfurization, denitration and waste heat recovery integrated method
CN104941423A (en) 2015-05-20 2015-09-30 江苏新世纪江南环保股份有限公司 Ammonia desulfurization and denitrification dedusting method and device utilizing catalytic cracking regeneration flue gas
CN105110819A (en) 2015-07-22 2015-12-02 江苏新世纪江南环保股份有限公司 Method used for producing sulfur-based urea compound fertilizer from ammonia desulphurization by-products
CN105126573A (en) 2015-07-22 2015-12-09 江苏新世纪江南环保股份有限公司 Integrated ammonia-process desulfurization method of various acidic gases in oil refining device
CN205562498U (en) 2015-12-15 2016-09-07 南京新世纪江南环保科技发展有限公司 Sealed pH meter interface
CN205252722U (en) 2015-12-17 2016-05-25 南京新世纪江南环保科技发展有限公司 Defroster subassembly
CN205549846U (en) 2015-12-17 2016-09-07 南京新世纪江南环保科技发展有限公司 Double -deck defroster subassembly
CN205252720U (en) 2015-12-17 2016-05-25 南京新世纪江南环保科技发展有限公司 House rigde mounting structure of defroster module
CN205252721U (en) 2015-12-17 2016-05-25 南京新世纪江南环保科技发展有限公司 Double -deck defroster subassembly of buckle blade
CN205235588U (en) 2015-12-17 2016-05-18 南京新世纪江南环保科技发展有限公司 Defroster mounting
CN205262780U (en) 2015-12-29 2016-05-25 南京新世纪江南环保科技发展有限公司 Can sealed thief hatch
CN205245200U (en) 2015-12-29 2016-05-18 南京新世纪江南环保科技发展有限公司 Chimney water smoke connects and draws dish
CN105841168A (en) 2016-03-23 2016-08-10 江苏新世纪江南环保股份有限公司 Integrated treatment method for malodorous VOCs gas of refining devices
CN105757688A (en) 2016-03-23 2016-07-13 江苏新世纪江南环保股份有限公司 Method and system for treating VOCs gas in sewage treatment plant

Non-Patent Citations (17)

* Cited by examiner, † Cited by third party
Title
"Advantages & Application of Efficient Ammonia-Based Desulfurization Technology," Jiangnan Environmental Technology, Inc., 19th Annual Electric Power Conference and Exhibition, Apr. 13, 2017, Chicago, Illinois.
"Introduction to FGD for China Shenhua Coal to Liquid(CTL) Project," Jiangnan Environmental Technology, Inc., 19th Annual Electric Power Conference and Exhibition, Apr. 13, 2017, Chicago, Illinois.
Google Patents English translation of CN100428979C, 2008.
Google Patents English translation of CN10322392A, 2013.
Google Patents English translation of CN1283346C, 2006.
Google Patents English translation of CN201912885U, 2011.
Google Patents English translation of CN2640585Y, 2004.
Google Patents English translation of CN2772609Y, 2006.
International Search Report issued for International Application No. PCT/CN2013/074657, dated Dec. 26, 2013.
International Search Report issued for International Application No. PCT/CN2014/087887, dated Jan. 14, 2015.
Office Action issued by the Japanese Intellectual Property Office in Japanese Application No. 2017-123088, dated Apr. 16, 2018.
Office Action issued in U.S. Appl. No. 14/829,905 dated Feb. 29, 2016.
Office Action issued in U.S. Appl. No. 14/829,905 dated Nov. 16, 2015.
Office Action issued in U.S. Appl. No. 14/829,909 dated Apr. 15, 2016.
Office Action issued in U.S. Appl. No. 14/829,909 dated Dec. 14, 2016.
Office Action issued in U.S. Appl. No. 14/829,909 dated Feb. 14, 2017.
Supplementary European Search Report issued in European Application No. 13882863.7, dated Mar. 11, 2016.

Cited By (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10343110B2 (en) * 2017-05-25 2019-07-09 Jiangnan Environmental Protection Group Inc. Dust removal and desulfurization of FCC exhaust gas
US10471383B2 (en) * 2017-05-25 2019-11-12 Jiangnan Environmental Protection Group Inc. Dust removal and desulfurization of FCC exhaust gas
US11224838B2 (en) 2019-12-26 2022-01-18 Jiangnan Environmental Protection Group Inc. Controlling aerosol production during absorption in ammonia-based desulfurization
CN111579437A (en) * 2020-05-27 2020-08-25 丹晟实业（上海）有限公司 Extraction testing arrangement of sulphur and nitrogen element content in haydite
CN111579437B (en) * 2020-05-27 2023-04-07 丹晟实业（上海）有限公司 Extraction testing arrangement of sulphur and nitrogen element content in haydite
CN111821856A (en) * 2020-07-29 2020-10-27 湖南萃智环保科技有限公司 Industrial flue gas denitration method
CN113384988A (en) * 2021-07-07 2021-09-14 西安鼎华联创工程技术有限公司 Ultra-clean dust removal system and dust removal method for dust removal and white removal of steel converter
CN114367164A (en) * 2021-12-23 2022-04-19 江苏徐海环境监测有限公司 Low-concentration large-flow high-efficiency waste gas treatment complete device
CN114307492A (en) * 2021-12-29 2022-04-12 山东赛马力发电设备有限公司 Generating set exhaust treatment system
CN114307492B (en) * 2021-12-29 2024-01-09 山东赛马力发电设备有限公司 Generating set exhaust treatment system
CN114353061A (en) * 2021-12-31 2022-04-15 北京博奇电力科技有限公司 Sintering flue gas ultralow emission system and method based on circulating fluidized bed desulfurization
CN118543241A (en) * 2024-07-24 2024-08-27 北京中科润宇环保科技股份有限公司 Purification method and device for tail gas produced by denitration catalyst

Also Published As

Publication number Publication date
CA2971738C (en) 2018-06-26
US20190282957A1 (en) 2019-09-19
US10343110B2 (en) 2019-07-09
US20190054419A1 (en) 2019-02-21
US20180339266A1 (en) 2018-11-29
JP2018009781A (en) 2018-01-18
JP6397967B2 (en) 2018-09-26
EP3406320A1 (en) 2018-11-28
CN107213785B (en) 2020-08-07
KR102022305B1 (en) 2019-09-18
US10471383B2 (en) 2019-11-12
WO2018214990A1 (en) 2018-11-29
KR20180129588A (en) 2018-12-05
MX2017008446A (en) 2019-02-08
US10213739B2 (en) 2019-02-26
CL2017001698A1 (en) 2018-02-16
CN107213785A (en) 2017-09-29
CA2971738A1 (en) 2017-08-29
EP3406320B1 (en) 2020-08-12
BR102017013544B1 (en) 2020-11-10

Similar Documents

Publication Publication Date Title
US10471383B2 (en) Dust removal and desulfurization of FCC exhaust gas
US10413864B2 (en) Method and apparatus for removing sulfur oxides from gas
KR102302849B1 (en) Method for controlling aerosol production during absorption in ammonia desulfurization
US7632475B2 (en) Process for removing contaminants from gas streams
CN108554145B (en) Flue gas desulfurization, denitrification, dust removal and whitening device
CN106659971A (en) Method and apparatus for removing contaminants from exhaust gases
US20100061906A1 (en) Method and a device for removing nitrogen oxides and sulphur trioxide from a process gas
CN101254394A (en) Sintering device flue gas multiple pollutant removing process and system thereof
CN102489149A (en) Flue-gas purification and reclamation system and method thereof
CN205700077U (en) A kind of device removing coke oven flue SO 2 in waste gas and nitrogen oxides
CN106178725A (en) The desulphurization denitration dust collecting process of a kind of glass kiln and device
CN215863435U (en) Industrial waste&#39;s processing apparatus
TW202010565A (en) Aerosol generation controlling method during absorption process of ammonia desulfurization capable of realizing highly efficient desulfurization and dust removal while controlling ammonia escape and aerosol generation
CN114849431A (en) Air box assembly, clinker production device and flue gas pollutant treatment equipment
CN208389772U (en) The out of stock system of the iron ammonia process of desulfurization
CN101632895B (en) Method for desulfurizing sintering flue gas
CN204841381U (en) SOx/NOx control integration system
CN221788840U (en) Catalytic cracking regeneration flue gas treatment device and catalytic cracking regeneration system
CN109200782A (en) A kind of organic flue gas semi-dry desulfurization and denitrification technique of high concentration
SO 16 FCC Emission Reduction
Schuttenhelm et al. Anthony Licata
BR102017013544A2 (en) METHOD AND APPARATUS FOR DYNITRATION AND DISCLOSURE OF AND REMOVAL OF FCC TAIL GAS POWDER THROUGH AMMONIUM-BASED PROCESS

Legal Events

Date Code Title Description
STCF Information on status: patent grant

Free format text: PATENTED CASE

MAFP Maintenance fee payment

Free format text: PAYMENT OF MAINTENANCE FEE, 4TH YEAR, LARGE ENTITY (ORIGINAL EVENT CODE: M1551); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY

Year of fee payment: 4